UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT
PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
Date of Report (Date of earliest events reported) June 12, 2003
--------------------------
(June 12, 2003)
--------------------------
Commission Name of Registrants, State of Incorporation, I.R.S. Employer
File Number Address and Telephone Number Identification No.
----------- -------------------------------------------- ------------------
333-32170 PNM Resources, Inc. 85-0468296
(A New Mexico Corporation)
Alvarado Square
Albuquerque, New Mexico 87158
(505) 241-2700
1-6986 Public Service Company of New Mexico 85-0019030
(A New Mexico Corporation)
Alvarado Square
Albuquerque, New Mexico 87158
(505) 241-2700
------------------------------
(Former name, former address and former fiscal year,
if changed since last report)
Item 5. Other Events
PNM Resources, Inc. and Public Service Company of New Mexico
(collectively the "Company") conform their presentation of information contained
in their 2002 Annual Report on Form 10-K to reflect matters previously disclosed
in their First Quarter 2003 Quarterly Report on Form 10-Q.
During 2002, the Company's Utility Operations business segment evolved.
On January 28, 2003, the New Mexico Public Regulation Commission ("PRC")
approved the Global Electric Agreement which sets a rate path through 2007.
Pursuant to the Global Electric Agreement, Electric Services ("Electric") became
a fully integrated retail energy supply business. As a result of that evolution,
the Company's generation activities changed from a stand-alone operation to a
function that became mostly integrated with the distribution energy supply
business, which primarily serves to optimize the value of that business. As
specified in the Global Electric Agreement, the Company's generation activities
were designated to support either its rate-regulated electric retail customers
or its wholesale customers. Therefore, upon review and in accordance with SFAS
No. 131, "Disclosures About Segments of an Enterprise and Related Information"
("SFAS 131"), and as disclosed in the Company's Form 10-Q for the quarter ended
March 31, 2003, the Company determined that Electric's generation and
distribution components no longer meet the definition of separate operating
segments for financial reporting purposes and the Company reported the financial
position and results of operations of the majority of its generation and
distribution activities as one segment. All prior periods have been reclassified
to conform to the current presentation and include certain estimates and
allocations where necessary.
This current report on Form 8-K ("report") conforms the information
contained in the Company's 2002 Annual Report on Form 10-K to the presentation
reported in its First Quarter 2003 Form 10-Q. Accordingly, this report revises
information previously reported in the Company's 2002 Annual Report on Form 10-K
to reflect the following matters which have previously been disclosed in reports
filed under the Securities Exchange Act of 1934.
No attempt has been made in this Form 8-K to modify or update other
disclosures as presented in the original Form 10-K except as required to reflect
the effects of those items as described below.
This report is limited to the reclassifications to reflect:
o a change in business segment reporting;
o a change in the reporting of trading revenues and costs; and
o removal of non-GAAP financial measures from the Company's 2002 Annual
Report on Form 10-K.
As disclosed in the Company's Form 10-Q for the quarter ended March 31,
2003, in accordance with the consensus reached in October 2002 relating to EITF
Issue No. 02-3, "Issues Involved in Accounting for Derivative Contracts Held for
Trading Purposes and Contracts Involved in Energy Trading and Risk Management
Activities" ("EITF 02-3") and EITF 98-10 "Accounting for Contracts Involved in
Energy Trading and Risk Management Activities ("EITF 98-10"), beginning in the
first quarter of 2003, the Company reclassified prior periods for those
contracts previously accounted for under EITF 98-10 to conform to a net margin
presentation as required by EITF 02-3. As a result, both operating revenues and
cost of energy sold were reduced by approximately $74.0 million, $89.4 million
and $99.7 million for the fiscal years ended December 31, 2002, 2001 and 2000,
respectively. This change in presentation did not have an effect on gross
margins, net income or cash flows.
2
In conjunction with filing this Report, the Company's Chief Executive
Officer and the Company's Chief Financial Officer have performed the procedures
necessary to evaluate the effectiveness of the Company's disclosure controls and
procedures, as required by Section 302 (a) (4) (c) of the Sarbanes-Oxley Act of
2002. Based on this evaluation, the Company believes that the Company's
disclosure controls and procedures to update the Company's 2002 Form 10-K as
described in Item 5 of this Report, are effective in that they provide
reasonable assurance that material information is made known so that it may be
included in the Report.
Such officers do not believe there have been significant changes in
internal controls or in other factors based on their evaluation on June 5, 2003
that could significantly affect internal controls, including any corrective
actions with regard to significant deficiencies and material weaknesses.
TABLE OF CONTENTS
Page
Updated information for the year ended December 31, 2002:
THE COMPANY................................................................4
UTILITY OPERATIONS.........................................................4
WHOLESALE OPERATIONS.......................................................6
CORPORATE AND OTHER........................................................7
SOURCES OF POWER...........................................................7
FUEL AND WATER SUPPLY......................................................7
EMPLOYEES..................................................................8
SELECTED FINANCIAL DATA....................................................9
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS.......................................10
OVERVIEW.........................................................10
COMPETITIVE STRATEGY.............................................10
RESULTS OF OPERATIONS............................................11
NEW AND PROPOSED ACCOUNTING STANDARDS............................32
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA...............................34
SIGNATURE................................................................109
3
THE COMPANY
PNM Resources, Inc. ("Holding Company") was incorporated in the State of
New Mexico on March 3, 2000. The Holding Company's principal subsidiary Public
Service Company of New Mexico ("PNM") was incorporated in the State of New
Mexico on May 9, 1917. This filing for PNM Resources, Inc. and Subsidiaries and
PNM is presented on a combined basis. The Holding Company and PNM have their
principal offices at Alvarado Square, Albuquerque, New Mexico 87158 (telephone
number 505-241-2700). The Holding Company is an investor-owned holding company
of energy and energy-related companies. PNM is a public utility primarily
engaged in the generation, transmission, distribution, sale and marketing of
electricity, and in the transmission, distribution and sale of natural gas
within the State of New Mexico. The business of PNM constitutes substantially
all of the business of PNM Resources, Inc. and Subsidiaries. Therefore, the
financial results and results of operations of PNM are virtually identical to
the consolidated results of the Holding Company and all its subsidiaries. For
ease of discussion, this report may use the term "Company" when referring to PNM
or when discussing matters of common applicability to the Holding Company and
PNM.
Upon the completion on December 31, 2001 of a one-for-one share exchange
between PNM and the Holding Company, the Holding Company became the parent
company of PNM. Prior to the share exchange, the Holding Company had existed as
a subsidiary of PNM. The new parent company began trading on the New York Stock
Exchange under the same PNM symbol beginning on December 31, 2001.
As it currently operates, the Company's principal business segments are
Utility Operations, Wholesale Operations ("Wholesale") and Corporate and Other.
Utility Operations include Electric Services ("Electric") and Gas Services
("Gas"). Electric consists of the distribution, transmission and generation of
electricity for retail electric customers in New Mexico. Gas includes the
transportation and distribution of natural gas to end-users. Wholesale consists
of the generation and sale of electricity into the wholesale market based on
three product lines, which are long-term contracts, forward sales and short-term
sales.
UTILITY OPERATIONS
Electric
The Company provides jurisdictional retail electric service to a large
area of north central New Mexico, including the City of Albuquerque ("COA") and
the City of Santa Fe, and certain other areas of New Mexico. The largest retail
electric customer served by the Company accounted for approximately 4.8% of the
Company's total retail electric revenues for the year ended December 31, 2002.
For the years 2000 through 2002, retail KWh sales have grown at a
compound annual rate of approximately 2.4%. The Company's system peak demands
for its retail customers and firm requirements customers in summer and winter
for the last three years are shown in the following table:
4
SYSTEM PEAK DEMANDS
(Megawatts)
2002 2001 2000
--------- --------- ---------
Summer............................ 1,456 1,397 1,368
Winter............................ 1,297 1,294 1,211
The Company holds long-term, non-exclusive franchise agreements for its
electric retail operations, expiring between May 2003 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, San Miguel
County, Village of Bosque Farms, Pueblo de Cochiti and Village of Tijeras
franchises have expired. The COA metropolitan area accounted for approximately
53% of the Company's 2002 total electric utility operating revenues, and no
other franchise area represents more than approximately 8%. The Company
continues to collect and pay franchise fees to the COA, City of Santa Fe, the
Town of Cochiti Lake, Village of Bosque Farms and Village of Tijeras. The
Company currently does not pay franchise fees to Bernalillo County, Luna County,
Sandoval County and San Miguel County. The Company remains obligated under New
Mexico state law to provide service to customers in these franchise areas even
in the absence of a franchise agreement.
The Company owns or leases 2,897 circuit miles of transmission lines,
interconnected with other utilities in New Mexico, east and south into Texas,
west into Arizona, and north into Colorado and Utah. Due to rapid load growth in
the Company's service territory in recent years and the lack of transmission
development, most of the capacity on this transmission system is fully committed
and there is very little or no additional access available on a firm commitment
basis. These factors result in physical constraints on the system and limit the
ability to wheel power into the Company's service area from outside New Mexico.
Gas
Gas operations distributes natural gas to most of the major communities
in New Mexico, including the COA and the City of Santa Fe. The COA metropolitan
area accounted for approximately 44% of the total gas revenues in 2002. No
single sales-service customer accounted for more than approximately 1% of the
Company's therm sales in 2002. The Company holds long-term, non-exclusive
franchises with varying expiration dates in all incorporated communities
requiring franchise agreements except for the COA, City of Santa Fe, Aztec,
Village of Bosque Farms, Town of Cochiti Lake, Los Ranchos de Albuquerque and
Tatum. The Company remains obligated to serve these franchise areas pursuant to
state law even in the absence of a franchise agreement.
The Company's customer base includes both sales-service customers and
transportation-service customers. Sales-service customers purchase natural gas
and receive transportation and delivery services from the Company for which the
Company 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 regulations and represent a pass-through of the Company's
cost of natural gas to the customer. Since the Company obtains its natural gas
5
supply on the open market from non-affiliated third-party producers, the
Company's operating results are not affected by an increase or decrease in
natural gas prices. Additionally, the Company makes occasional gas sales to
off-system customers. Off-system sales deliveries generally occur at interstate
pipeline interconnects with the Company's system.
Transportation-service customers, who procure gas independently of the
Company and contract with the Company for transportation and related services,
provide the Company with cost-of-service revenues only. Transportation services
are provided to gas marketers, producers and end users for delivery to locations
throughout its distribution systems, as well as for delivery to interstate
pipelines. The Company provided gas transportation deliveries to approximately
1,360 gas marketers, producers and end users during 2002.
During 2002, approximately 49% of the Company's total gas throughput was
related to transportation gas deliveries. The Company's transportation rates are
unbundled, and transportation customers only pay for the service they receive.
Cost-of-gas revenues, received from sales-service and off-system customers, and
other PGAC-related revenues accounted for approximately 51% of the Company's
total gas operating revenues in 2002. Since a major portion of the Company's
load is related to heating, levels of therm sales are affected by weather.
Approximately 63% of the Company's total therm sales in 2002 occurred in the
months of January, February, March and December.
The Company obtains its supply of natural gas primarily from sources
within New Mexico by contracting with third party producers and marketers. These
contracts are generally sufficient to meet the Company's peak-day demand. The
Company 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 the Company's 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, the
Company's options for transporting gas to these cities and other portions of its
distribution system have increased.
WHOLESALE OPERATIONS
The Company's Wholesale Operations consists of the generation and sale of
electricity into the wholesale market based on three product lines, which are
long-term contracts, forward sales and short-term sales. Long-term contracts
include sales to firm-requirements wholesale customers with multi-year
arrangements. These contracts range from 2 to 17 years with an average of 7.5
years. Forward sales include sales of excess generation and third party
purchases in the forward market that range from 1 month to 3 years. These
transactions do not qualify as normal sales and purchases as defined in SFAS 133
and as a result, are generally marked to market. Short-term sales generally
include spot market, hour ahead, day ahead and week ahead contracts with terms
of 30 days or less. Also included are sales of any excess generation not
required to fulfill PNM's retail load and contractual commitments. Short-term
sales also cover the revenue credit to retail customers as specified in the
Global Electric Agreement.
The Wholesale Operations strategy calls for increased asset-backed energy
sales supported by long-term contracts and the wholesale market. The
asset-backed sales are actively monitored by management by the use of stringent
risk management policies. The Company's future growth plans call for
approximately 75% of its new generation portfolio to be committed through
long-term contracts, including sales to retail customers. Growth will be
dependent on market development, and upon the Company's ability to generate
funds for the Company's future expansion. Although the current economic
6
environment has led the Company to scale back its expansion plans, the Company
will continue to operate in the wholesale market and seek rationally priced
asset additions. Expansion of the Company's generating portfolio will depend
upon acquiring favorably priced assets at strategic locations and securing
long-term commitments for the purchase of power from the acquired plants.
Power Sales
All information disclosed under power sales in the 2002 Annual Report on
Form 10-K remains the same except for the Wholesale strategy as discussed above.
CORPORATE AND OTHER
(formerly Unregulated Operations)
The Holding Company incurs substantially all of the corporate activities
of PNM. These activities are billed to PNM on a cost basis to the extent they
are for the corporate management of PNM and are allocated to the operating
segments. The Holding Company's wholly-owned subsidiary, Avistar, was formed in
August 1999 as a New Mexico corporation and is currently engaged in certain
unregulated and non-utility businesses. In January 2002, Avistar was transferred
by way of a dividend to the Holding Company pursuant to an order from the PRC.
SOURCES OF POWER
Previously in the 2002 Annual Report on Form 10-K, the Company disclosed
sources of power under its Generation and Marketing business segment. As the
generation activities of the Company now support both the Electric and Wholesale
business segments, this section now applies to both business segments.
FUEL AND WATER SUPPLY
Previously in the 2002 Annual Report on Form 10-K, the Company disclosed
fuel and water supply under its Generation and Marketing business segment. As
the generation activities of the Company now support both the Electric and
Wholesale business segments, this section now applies to both business segments.
(Intentionally left blank)
7
EMPLOYEES
As of December 31, 2002, the Company had 2,656 full-time employees. The
following table sets forth the number of employees by business segment as of
December 31, 2002:
Number
----------
Corporate (1)........................... 426
Electric Services....................... 1,613
Gas Services............................ 526
Wholesale Operations.................... 78
Corporate and Other..................... 13
----------
Total................................ 2,656
==========
(1) These employees resided at the Holding Company at December 31, 2002.
The number of employees of the Company who are represented by unions or other
collective bargaining groups include (i) Electric 536; (ii) Gas 56; and (iii)
Wholesale 48.
(Intentionally left blank)
8
SELECTED FINANCIAL DATA
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.
2002 2001 2000 1999 1998
------------- ------------- ------------- ------------ -------------
(In thousands except per share amounts and ratios)
Total Operating Revenues............................... $1,095,009 $2,250,466 $1,511,539 $1,092,445 $1,111,343
Earnings from Continuing Operations.................... $ 64,272 $ 150,433 $ 100,946 $ 79,614 $ 95,119
Net Earnings........................................... $ 64,272 $ 150,433 $ 100,946 $ 83,155 $ 82,682
Earnings per Common Share:
Continuing Operations................................ $ 1.63 $ 3.83 $ 2.54 $ 1.93 $ 2.27
Basic................................................ $ 1.63 $ 3.83 $ 2.54 $ 2.01 $ 1.97
Diluted.............................................. $ 1.61 $ 3.77 $ 2.53 $ 2.01 $ 1.95
Cash Flow Data:
Net cash flows provided from operating activities.... $ 97,251 $ 327,346 $ 239,515 $ 213,045 $ 210,988
Net cash flows used in investing activities.......... $ (200,427) $ (407,014) $ (157,500) $ (55,886) $ (340,992)
Net cash flows generated (used)
by financing activities........................... $ 78,470 $ 385 $ (94,723) $ (98,040) $ 173,089
Total Assets........................................... $3,026,907 $2,913,788 $2,889,917 $2,723,268 $2,668,603
Long-Term Debt, including current maturities........... $ 980,092 $ 953,884 $ 953,823 $ 988,489 $1,008,614
Common Stock Data:
Market price per common share at year end............ $ 23.820 $ 27.950 $ 26.813 $ 16.250 $ 20.438
Book value per common share at year end.............. $ 24.90 $ 25.87 $ 23.42 $ 21.79 $ 20.63
Average number of common shares outstanding.......... 39,118 39,118 39,487 41,038 41,774
Cash dividend declared per common share.............. $ 0.88 $ 0.80 $ 0.80 $ 1.00 $ 0.60
Return on Average Common Equity...................... 6.2 % 14.8 % 11.1 % 9.5 % 9.9 %
Capitalization:
Common stock equity.................................. 49.2 % 50.8 % 48.6 % 46.7 % 45.4 %
Preferred stock without mandatory redemption
Requirements....................................... 0.7 0.6 0.7 0.7 0.7
Long-term debt, less current maturities.............. 50.1 48.6 50.7 52.6 53.9
------------- ------------- ------------- ------------- -------------
100.00 % 100.00 % 100.00 % 100.00 % 100.00 %
============= ============= ============= ============= =============
(See "Comparative Operating Statistics" which appear immediately
following the Consolidated Financial Statements for additional information
regarding operations.)
Due to the discontinuance of the natural gas trading operations of PNM's
Energy Services Business Unit in 1998, certain prior year amounts have been
reclassified as discontinued operations.
9
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
CONDITION AND RESULTS OF OPERATIONS
The Management's Discussion and Analysis of Financial Condition and
Results of Operations for PNM Resources, Inc. ("Holding Company") and its
Subsidiaries and Public Service Company of New Mexico ("PNM") (collectively, the
"Company") is presented on a combined basis. The Holding Company assumed
substantially all of the corporate activities of PNM on December 31, 2001. These
activities are billed to PNM on a cost basis to the extent they are for the
corporate management of PNM. In January 2002, Avistar, Inc. ("Avistar") and
certain inactive subsidiaries were transferred by way of a dividend to the
Holding Company pursuant to an order from the New Mexico Public Regulation
Commission ("PRC"). The reader of this Management's Discussion and Analysis of
Financial Condition and Results of Operations should assume that the information
presented applies to consolidated results of operations and financial position
of both PNM Resources, Inc. and Subsidiaries and PNM, except where the context
or references clearly indicate otherwise. Discussions regarding specific
contractual obligations generally reference the company that is legally
obligated. In the case of contractual obligations of PNM, these obligations are
consolidated with PNM Resources, Inc. and its Subsidiaries under Generally
Accepted Accounting Principles ("GAAP"). Broader operational discussion
references the Company.
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 related notes. Trends and contingencies of a material
nature are discussed to the extent known and considered relevant.
OVERVIEW
The Holding Company is an investor-owned holding company of energy and
energy related companies. Its principal subsidiary, PNM, is an integrated public
utility primarily engaged in the generation, transmission, distribution and sale
and marketing of electricity; transmission, distribution and sale of natural gas
within the State of New Mexico; and the sale and marketing of electricity in the
Western United States.
Upon the completion on December 31, 2001 of a one-for-one share exchange
between PNM and the Holding Company, the Holding Company became the parent
company of PNM. Prior to the share exchange, the Holding Company had existed as
a subsidiary of PNM. The new parent company began trading on the New York Stock
Exchange under the same PNM symbol beginning on December 31, 2001.
COMPETITIVE STRATEGY
The Company is positioned as a "merchant utility," primarily operating as
a regulated energy service provider. The Company is also engaged in the sale and
marketing of electricity in the competitive energy market place. As a utility,
PNM has an obligation to serve its customers under the jurisdiction of the PRC.
As a wholesale electricity provider, PNM markets excess production from the
utility, as well as unregulated generation, into a competitive marketplace. As
part of its electric wholesale power operation, the Company may purchase
10
wholesale electricity in the open market for future resale or to provide energy
to retail customers in New Mexico when the Company's generation assets cannot
satisfy demand. The wholesale operations utilize an asset-backed strategy,
whereby the Company's aggregate net open position for the sale of electricity is
covered by the Company's forecasted excess generation capabilities.
As it currently operates, the Company's principal business segments are
Utility Operations, Wholesale Operations ("Wholesale") and Corporate and Other.
Utility Operations include Electric Services ("Electric") and Gas Services
("Gas"). Electric consists of the distribution, transmission and generation of
electricity for retail customers in New Mexico. Gas includes the transportation
and distribution of natural gas to end-users. Wholesale consists of the
generation and sale of electricity into the wholesale market based on three
product lines which are long-term contracts, forward sales and short-term sales.
The Utility Operations strategy is directed at supplying reasonably
priced and reliable energy to retail customers through customer-driven
operational excellence, high quality customer service, cost efficient processes,
and improved overall organizational performance.
The Wholesale Operations strategy calls for increased asset-backed energy
sales supported by long-term contracts and the wholesale market. The
asset-backed sales are actively monitored by management by the use of stringent
risk management policies. The Company's future growth plans call for
approximately 75% of its new generation portfolio to be committed through
long-term contracts, including sales to retail customers. Growth will be
dependent on market development, and upon the Company's ability to generate
funds for the Company's future expansion. Although the current economic
environment has led the Company to scale back its expansion plans, the Company
will continue to operate in the wholesale market and seek rationally priced
asset additions. Expansion of the Company's generating portfolio will depend
upon acquiring favorably priced assets at strategic locations and securing
long-term commitments for the purchase of power from the acquired plants.
RESULTS OF OPERATIONS
Year Ended December 31, 2002 Compared to Year Ended December 31, 2001
Consolidated
The Company's net earnings available to common shareholders for the year
ended December 31, 2002 were $63.7 million, a 57.5% decrease in net earnings
from $149.8 million in 2001. This decrease primarily reflects the slowdown in
the wholesale electric market, where both prices and market liquidity were
significantly lower than the prior year. Despite the slowdown in the wholesale
electric market, PNM's electric utility operations recorded a gross margin
growth of 3.3%. This growth came from a combination of load growth and
utilization of lower cost generation demonstrating the balance the regulated
utility provides in the Company's "merchant utility" strategy.
11
The following discussion is based on the financial information presented
in the Consolidated Financial Statements - Segment Note as updated in this Form
8-K (see Note (2)). Corporate allocations, income taxes and non-operating items
are discussed only on a consolidated basis.
Utility Operations
The following presentation sets forth the operating results for Electric
(inclusive of transmission activities) for fiscal year 2002 compared to 2001.
Subsequent to filing the Form 10-Q for the quarter ended March 31, 2003, the
Company changed the segment reporting for Utility Operations to disaggregate its
presentation of Electric and transmission activities ("Transmission"). Based on
this change, set forth below also is a presentation of the operating results for
Electric (without Transmission) and for Transmission, in each case for the
fiscal year 2002 compared to 2001.
Electric
The table below sets forth the operating results for Electric.
Year Ended December 31,
---------------------------------
2002 2001 Variance
-------------- -------------- -------------
(In thousands)
Operating revenues............................... $570,089 $559,226 $10,863
Less: Cost of energy............................. 166,101 162,884 3,217
Energy transfer........................... (28,037) (21,999) (6,038)
-------------- -------------- --------------
Gross margin..................................... 432,025 418,341 13,684
-------------- -------------- --------------
Energy production costs.......................... 116,260 121,277 (5,017)
Transmission and distribution O&M................ 34,517 37,853 (3,336)
Customer related expense......................... 17,480 19,388 (1,908)
Administrative and general....................... 7,344 10,553 (3,209)
-------------- -------------- --------------
Total non-fuel O&M............................. 175,601 189,071 (13,470)
Corporate allocation............................. 56,116 59,084 (2,968)
Depreciation and amortization.................... 71,210 66,680 4,530
Taxes other than income taxes.................... 20,823 18,524 2,299
Income taxes..................................... 29,605 19,230 10,375
-------------- -------------- --------------
Total non-fuel operating expenses.............. 353,355 352,589 766
-------------- -------------- --------------
Operating income................................. $78,670 $65,752 $12,918
-------------- -------------- --------------
12
The following table shows electric revenues by customer class and average
customers:
Electric Revenues
Year Ended
December 31,
--------------------------------
2002 2001 Variance
-------------- -------------- --------------
(In thousands)
Residential.............. $ 197,174 $ 187,600 $9,574
Commercial............... 247,800 242,372 5,428
Industrial............... 82,009 82,752 (743)
Transmission............. 23,150 26,553 (3,403)
Other.................... 19,956 19,949 7
-------------- -------------- --------------
$ 570,089 $ 559,226 $10,863
============== ============== ==============
Average customers........ 384,478 377,589 6,889
============== ============== ==============
The following table shows electric sales by customer class:
Electric Sales
(Megawatt hours)
Year Ended
December 31,
--------------------------------
2002 2001 Variance
--------------- -------------- ---------------
(In thousands)
Residential........... 2,298,542 2,197,889 100,653
Commercial............ 3,254,576 3,213,208 41,368
Industrial............ 1,612,723 1,603,266 9,457
Other................. 240,665 240,934 (269)
--------------- -------------- ---------------
7,406,506 7,255,297 151,209
=============== ============== ===============
Operating revenues increased $10.9 million or 1.9% for the period to
$570.1 million. Retail electricity delivery grew 2.1% to 7.4 million MWh in 2002
compared to 7.3 million MWh delivered in the prior year, resulting in increased
revenues of $14.4 million year-over-year. This volume increase was the result of
a weather-driven increase in consumption and continued customer growth. Year
over year, customer growth was 1.8%. This increase in revenues was partially
offset by a decrease of $3.4 million in revenues from third party sales of the
Company's transmission capacity due to the slowdown in the wholesale market
The gross margin, or operating revenues minus cost of energy sold,
increased $13.7 million or 3.3%, which reflects the increased energy sales and
the utilization of lower cost purchased power to serve jurisdictional needs
based on a change in negotiated contract rates.
Total non-fuel O&M decreased $13.5 million or 7.1%. Energy production
costs decreased $5.0 million or 4.1% for the period reflecting the benefits of
$2.0 million for the acceleration into 2001 of a planned outage at San Juan
Generating Station ("SJGS"), decreased costs of $3.0 million for planned outages
at SJGS and an adjustment of $3.1 million to prior year Palo Verde Nuclear
13
Generating Station ("PVNGS") billings from Arizona Public Service Company, the
operator of PVNGS. These cost decreases were partially offset by severance costs
of $1.4 million at PVNGS and Four Corners Power Plant ("Four Corners") and costs
of $1.2 million for planned and unplanned outages at Four Corners. Transmission
and distribution costs decreased $3.3 million or 8.8% primarily due to
maintenance performed in 2001 to improve system reliability, which did not recur
in 2002. Customer related expense decreased $1.9 million or 9.8% due to lower
bad debt expense as a result of collection improvements and the absence of
losses from the bankruptcy of a significant customer in 2001. Administrative and
other costs decreased $3.2 million or 30.4% due to an adjustment of $1.4 million
to prior year SJGS participant billings (the Company is the operator of SJGS and
shares costs with other owners) and lower labor due to the transfer of employees
from Electric to Corporate. Depreciation and amortization increased $4.5 million
or 6.8% for the year due to the purchase of transmission plant assets in early
2002 and a higher depreciable base. Taxes other than income increased $2.3
million or 12.4% reflecting adjustments recorded in the prior year for favorable
audit outcomes by certain tax authorities.
Electric (without Transmission)
The table below sets forth the operating results for Electric.
Year Ended December 31,
---------------------------------
2002 2001 Variance
-------------- -------------- -------------
(In thousands)
Operating revenues............................... $546,939 $532,673 $14,266
Less: Cost of energy............................. 194,163 189,055 5,108
Energy transfer........................... (28,037) (21,999) (6,038)
-------------- -------------- --------------
Gross margin..................................... 380,813 365,617 15,196
-------------- -------------- --------------
Energy production costs.......................... 115,570 120,353 (4,783)
Distribution O&M................................. 19,986 20,712 (726)
Customer related expense......................... 17,480 19,388 (1,908)
Administrative and general....................... 4,995 8,398 (3,403)
-------------- -------------- --------------
Total non-fuel O&M............................. 158,031 168,851 (10,820)
Corporate allocation............................. 51,425 54,488 (3,063)
Depreciation and amortization.................... 62,514 59,352 3,162
Taxes other than income taxes.................... 18,354 16,272 2,082
Income taxes..................................... 24,934 13,788 11,146
-------------- -------------- --------------
Total non-fuel operating expenses.............. 315,258 312,751 2,507
-------------- -------------- --------------
Operating income................................. $65,555 $52,866 $12,689
-------------- -------------- --------------
14
The following table shows electric revenues by customer class and average
customers:
Electric Revenues
Year Ended
December 31,
--------------------------------
2002 2001 Variance
-------------- -------------- --------------
(In thousands)
Residential................ $ 197,174 $ 187,600 $9,574
Commercial................. 247,800 242,372 5,428
Industrial................. 82,009 82,752 (743)
Other...................... 19,956 19,949 7
-------------- -------------- --------------
$ 546,939 $ 532,673 $14,266
============== ============== ==============
Average customers.......... 384,478 377,589 6,889
============== ============== ==============
The following table shows electric sales by customer class:
Electric Sales
(Megawatt hours)
Year Ended
December 31,
--------------------------------
2002 2001 Variance
--------------- -------------- ---------------
(In thousands)
Residential................. 2,298,542 2,197,889 100,653
Commercial.................. 3,254,576 3,213,208 41,368
Industrial.................. 1,612,723 1,603,266 9,457
Other....................... 240,665 240,934 (269)
--------------- -------------- ---------------
7,406,506 7,255,297 151,209
=============== ============== ===============
Operating revenues increased $14.3 million or 2.7% for the period to
$546.9 million. Retail electricity delivery grew 2.1% to 7.4 million MWh in 2002
compared to 7.3 million MWh delivered in the prior year, resulting in increased
revenues of $14.4 million year-over-year. This volume increase was the result of
a weather-driven increase in consumption and continued customer growth. Year
over year, customer growth was 1.8%.
The gross margin, or operating revenues minus cost of energy sold,
increased $15.2 million or 4.2%, which reflects the increased energy sales and
the utilization of lower cost purchased power to serve jurisdictional needs
based on a change in negotiated contract rates. Electric exclusively purchases
transmission services from Transmission. These intercompany revenues and
expenses are eliminated in the consolidated results.
Total non-fuel O&M decreased $10.8 million or 6.4%. Energy production
costs decreased $4.8 million or 4.0% for the period reflecting the benefits of
$2.0 million for the acceleration into 2001 of a planned outage at SJGS,
decreased costs of $3.0 million for planned outages at SJGS and an adjustment of
$3.1 million to prior year Palo Verde Nuclear Generating Station ("PVNGS")
billings from Arizona Public Service Company, the operator of PVNGS. These cost
15
decreases were partially offset by severance costs of $1.4 million at PVNGS and
Four Corners Power Plant ("Four Corners") and costs of $1.2 million for planned
and unplanned outages at Four Corners. Distribution costs decreased $0.7 million
or 3.5% primarily due to maintenance performed in 2001 to improve system
reliability, which did not recur in 2002. Customer related expense decreased
$1.9 million or 9.8% due to lower bad debt expense as a result of collection
improvements and the absence of losses from the bankruptcy of a significant
customer in 2001. Administrative and other costs decreased $3.4 million or 40.5%
due to an adjustment of $1.4 million to prior year SJGS participant billings and
lower labor due to the transfer of employees from Electric to Corporate.
Depreciation and amortization increased $3.2 million or 5.3% for the year due to
a higher depreciable plant base. Taxes other than income increased $2.1 million
or 12.8% reflecting adjustments recorded in the prior year for favorable audit
outcomes by certain tax authorities.
Transmission
The table below sets forth the operating results for Transmission.
Year Ended December 31,
-----------------------------------
2002 2001 Variance
---------------- ---------------- --------------
(In thousands)
Operating revenues
External customers............................. $23,150 $26,553 $ (3,403)
Intersegment revenues.......................... 31,950 31,273 677
---------------- ---------------- --------------
Total revenues............................... 55,100 57,826 (2,726)
Cost of energy................................... 3,888 5,102 (1,214)
---------------- ---------------- --------------
Gross margin..................................... 51,212 52,724 (1,512)
---------------- ---------------- --------------
Energy production costs.......................... 690 924 (234)
Transmission O&M ................................ 14,531 17,141 (2,610)
Administrative and general....................... 2,349 2,155 194
---------------- ---------------- --------------
Total non-fuel O&M............................. 17,570 20,220 (2,650)
---------------- ---------------- --------------
Corporate allocation............................. 4,691 4,596 95
Depreciation and amortization.................... 8,696 7,328 1,368
Taxes other than income taxes.................... 2,469 2,252 217
Income taxes..................................... 4,671 5,442 (771)
---------------- ---------------- --------------
Total non-fuel operating expenses.............. 38,097 39,838 (1,741)
---------------- ---------------- --------------
Operating income................................. $13,115 $12,886 $ 229
---------------- ---------------- --------------
Operating revenues decreased $2.7 million or 4.7% and gross margin
decreased $1.5 million or 2.9% primarily due to a decrease in third party sales
of the Company's transmission capacity due to the slowdown in the wholesale
market.
Total non-fuel O&M decreased $2.7 million or 13.1%. Transmission costs
decreased $2.6 million or 15.2% primarily due to maintenance performed in 2001
to improve system reliability, which did not recur in 2002. Depreciation and
amortization increased $1.4 million or 18.7% for the year due to the purchase of
transmission plant assets in early 2002.
16
Gas
The table below sets forth the operating results for Gas.
Year Ended December 31,
---------------------------------
2002 2001 Variance
--------------- -------------- ---------------
(In thousands)
Operating revenues............................... $272,118 $385,418 $(113,300)
Cost of energy................................... 139,045 251,296 (112,251)
--------------- -------------- ---------------
Gross margin..................................... 133,073 134,122 (1,049)
--------------- -------------- ---------------
Energy production costs.......................... 1,936 1,946 (10)
Distribution O&M................................. 29,306 31,064 (1,758)
Customer related expense......................... 16,604 19,814 (3,210)
Administrative and general....................... 4,247 6,736 (2,489)
--------------- -------------- ---------------
Total non-fuel O&M............................. 52,093 59,560 (7,467)
Corporate allocation............................. 31,316 30,908 408
Depreciation and amortization.................... 20,718 20,362 356
Taxes other than income taxes.................... 7,751 6,768 983
Income taxes..................................... 3,028 1,867 1,161
--------------- -------------- ---------------
Total non-fuel operating expenses.............. 114,906 119,465 (4,559)
--------------- -------------- ---------------
Operating income................................. $18,167 $14,657 $ 3,510
--------------- -------------- ---------------
The following table shows gas revenues by customer and average customers:
Gas Revenues
Year Ended
December 31,
--------------------------------
2002 2001 Variance
-------------- -------------- --------------
(In thousands)
Residential............. $ 172,200 $ 232,321 $(60,121)
Commercial.............. 52,530 68,895 (16,365)
Industrial.............. 2,872 27,519 (24,647)
Transportation*......... 17,735 20,188 (2,453)
Other................... 26,781 36,495 (9,714)
-------------- -------------- --------------
$ 272,118 $ 385,418 $(113,300)
============== ============== ==============
Average customers....... 443,396 434,591 8,805
============== ============== ==============
17
The following table shows gas throughput by customer class:
Gas Throughput
Year Ended
December 31,
--------------------------------
2002 2001 Variance
-------------- --------------- --------------
(Thousands of decatherms)
Residential................ 29,627 27,848 1,779
Commercial................. 12,009 10,421 1,588
Industrial................. 749 3,920 (3,171)
Transportation*............ 44,889 51,395 (6,506)
Other...................... 4,806 4,355 451
-------------- --------------- --------------
92,080 97,939 (5,859)
============== =============== ==============
* Customer owned gas
Operating revenues decreased $113.3 million or 29.4% for the period to
$272.1 million, primarily because of lower natural gas prices in 2002 as
compared to 2001 and a decrease in gas sales volumes of 6.0%, largely resulting
from fewer purchases from Electric and Wholesale to support gas-fired
generation. Despite the volume decline, customer growth was approximately 2.0%.
PNM purchases natural gas in the open market and resells it at cost to its
distribution customers. As a result, increases or decreases in gas revenues
driven by gas costs do not impact the Company's consolidated gross margin or
earnings.
The gross margin, or operating revenues minus cost of energy sold,
decreased $1.0 million or 0.8%. This decrease is due mainly to lower consumption
of gas for electric generation of $6.0 million partially offset by a 2.0% growth
in customer base of $5.0 million. Gross margin is expected to decrease in 2003
due to the expiration of a rate rider in January 2003. The Company currently
believes that gas assets are not earning an adequate level of return. As a
result, the Company filed a request for increased rates in January 2003. The
Company's last gas rate case filing was in October 1997.
Total non-fuel O&M decreased $7.5 million or 12.5%. Distribution costs
decreased $1.8 million or 5.7% primarily due to maintenance performed in 2001 to
improve system reliability, which did not recur in 2002. Customer related
expense decreased $3.2 million or 16.2% due to lower bad debt expense because of
collection improvements and the absence of losses from the bankruptcy of a
significant customer in 2001. Administrative and other costs decreased $2.5
million due to lower amortization costs of $1.2 million for SFAS 106 deferred
costs (which were fully amortized in 2001), and lower consulting expenses of
$0.5 million in connection with cost control and process improvement initiatives
in 2001 and lower legal expenses of $0.5 million for routine business matters.
Taxes other than income taxes increased $1.0 million or 14.5% due to the absence
of favorable audit outcomes by certain tax authorities recognized in 2001.
18
Wholesale
The table below sets forth the operating results for Wholesale.
Year Ended December 31,
-----------------------------------
2002 2001 Variance
---------------- -------------- ----------------
(In thousands)
Operating revenues............................. $251,398 $1,304,284 $(1,052,886)
Less: Cost of energy.......................... 170,110 1,020,754 (850,644)
Energy Transfer..................... 28,037 21,999 6,038
---------------- --------------- ----------------
Gross margin................................... 53,251 261,531 (208,280)
---------------- --------------- ----------------
Energy production costs........................ 31,377 29,309 2,068
Customer related expense....................... 646 821 (175)
Administrative and general..................... 4,514 4,748 (234)
---------------- --------------- ----------------
Total non-fuel O&M........................... 36,537 34,878 1,659
Corporate allocation........................... 3,777 4,042 (265)
Depreciation and amortization.................. 6,055 5,774 281
Taxes other than income taxes.................. 2,609 2,498 111
Income taxes................................... (4,147) 78,102 (82,249)
---------------- --------------- ----------------
Total non-fuel operating expenses............ 44,831 125,294 (80,463)
---------------- --------------- ----------------
Operating income............................... $ 8,420 $ 136,237 $ (127,817)
---------------- --------------- ----------------
The following table shows revenues by customer class:
Wholesale Revenues
Year Ended
December 31,
--------------------------------
2002 2001 Variance
-------------- -------------- ---------------
(In thousands)
Long-term contracts....... $ 40,132 $ 77,250 $ (37,118)
Other merchant sales...... 192,968 1,224,388 (1,031,420)
Other..................... 18,298 2,646 15,652
-------------- -------------- ---------------
$251,398 $1,304,284 $(1,052,886)
============== ============== ===============
The following table shows sales by customer class:
Wholesale Sales
Year Ended
December 31,
--------------------------------
2002 2001 Variance
-------------- --------------- --------------
(Megawatt hours)
Long-term contracts....... 844,168 1,463,031 (618,863)
Other merchant sales...... 7,269,242 10,596,004 (3,326,762)
-------------- --------------- --------------
8,113,410 12,059,035 (3,945,625)
============== =============== ==============
19
Operating revenues declined $1.1 billion or 80.7% for the year to $251.4
million. This decrease in wholesale electricity sales primarily reflects the
slowdown in the wholesale electric market, which resulted from steep declines in
wholesale prices and market liquidity as compared to the prior year period.
The significantly higher wholesale pricing in 2001 was driven by
increased demand in California, a lack of generating assets to serve the market
and the impact of warm weather. By contrast, 2002 has seen relatively mild
weather in the West, an abundance of low cost hydropower and weak economic
conditions in the region. As a result, the average price realized by the Company
fell to approximately $31 per MWh in 2002 versus $108 per MWh in 2001. The low
wholesale prices are expected to continue into 2003.
The decline in merchant sales volumes reflect the reduction in market
participants in the wholesale market caused by bankruptcy, reduced credit
quality of firms in the market and firms exiting the wholesale market. There are
also significant unresolved legal, political and regulatory issues that had a
dampening effect on activity in the marketplace. As a result, the Company's spot
market and short-term sales have declined significantly. The Company delivered
wholesale (bulk) power of 8.1 million MWh of electricity for the year ended
December 31, 2002, compared to 12.1 million MWh for the same period in 2001.
Although other firms have exited the wholesale market or have had their
access to the wholesale market limited due to concerns over credit quality, the
Company remains committed to be a participant in this market place. While market
liquidity is weak, the Company will focus on long-term relationships with
smaller wholesale customers (small investor-owned utilities, municipal utilities
and co-ops). At the same time, the Company will continue to monitor market
conditions. This commitment to the wholesale market leaves the Company poised to
participate in the market as liquidity returns and regulatory issues are
resolved.
The gross margin, or operating revenues minus cost of energy sold,
decreased $208.3 million or 79.6%. Lower margins were created primarily by weak
pricing, less price volatility and lower market liquidity. In addition,
unexpected outages at Four Corners reduced availability of power for wholesale
sales. These lower margins were partially offset by a favorable change in the
mark-to-market position of the marketing portfolio of $55.3 million
year-over-year ($29.5 million gain in 2002 versus $25.8 million loss in 2001). A
majority of the gain in 2002 represents the reversal of previously recognized
mark-to-market losses.
Total non-fuel O&M increased $1.7 million or 4.8%. Energy production
costs increased $2.1 million or 7.1% for the period due to costs of $4.0 million
related to the future expansion of Afton Generating Station ("Afton). This cost
increase was partially offset by the benefits of $0.3 million for the
acceleration into 2001 of a planned outage at SJGS, decreased costs of $0.5
million for planned outages at SJGS and an adjustment of $0.5 million to prior
year Palo Verde Nuclear Generating Station ("PVNGS") billings from Arizona
Public Service Company, the operator of PVNGS.
20
Corporate and Other
Corporate administrative and general costs, which represent costs that
are driven primarily by corporate-level activities, increased $3.3 million or
3.6% for the period to $95.1 million. This increase was due to severance costs
of $8.8 million resulting from a realignment of the Company's business structure
(the "Realignment"), higher labor of $8.2 million resulting from a transfer of
employees from operations to corporate and outside services of $2.9 million
primarily related to audit and other consulting services. These increases were
partially offset by lower bonus expense of $11.9 million in the current year
resulting from lower earnings projections and lower costs of $4.6 million
resulting from the reduction of certain unregulated activities. In accordance
with EITF 94-3, Liability Recognition for Certain Employee - Termination
Benefits and other Costs to Exit an Activity ("EITF 94-3"), the Company incurred
a liability of $8.8 million for severance and other related costs associated
with the involuntary termination of employees in connection with the
realignment. As of December 31, 2002, $3.0 million of severance-related benefits
were paid and charged against the liability.
Consolidating Non-Operating
Other Income and Deductions
Other income decreased by $3.8 million or 7.3% reflecting lower
year-over-year returns on investments reflecting market conditions.
Other deductions decreased $54.9 million or 81.7% primarily due to
charges in 2001 that did not recur in 2002. In 2001, the Company recognized
charges for the write-off of an Avistar investment of $13.1 million, the
write-off of non-recoverable coal mine decommissioning costs of $13.0 million,
non-recoverable regulatory costs of $11.1 million, a contribution to the PNM
Foundation of $5.0 million, and certain costs related to the Company's now
terminated acquisition of Western Resources' electric utility operations of
$18.0 million. In 2002, the Company recognized a gain from the reversal of a
reserve of $2.4 million to reflect the early, successful resolution of the
litigation stemming from the terminated Western Resources transaction and a
charge of $4.8 million for the cancellation of a transmission line project.
Income Taxes
The Company's consolidated income tax expense was $33.0 million for the
year ended December 31, 2002, compared to $81.1 million for the year ended
December 31, 2001. The decrease was due to the impact of lower earnings and a
decline in the effective tax rate. The Company's effective income tax rates for
the years ended December 31, 2002 and 2001 were 33.95% and 35.02%, respectively.
The decrease in the effective rate year over year was due to the reduction in
earnings in 2002 without a corresponding reduction in permanent tax benefits and
the recognition of certain affordable housing and research and development
credits in 2002.
21
Year Ended December 31, 2001 Compared to Year Ended December 31, 2000
Consolidated
The Company's net earnings available to common shareholders for the year
ended December 31, 2001 were $149.8 million, a 49.3% increase over net earnings
of $100.4 million in 2000. This increase reflects strong market pricing and an
active wholesale electric market in the Western United States in the first half
of 2001 and continuing growth in utility operations.
The following discussion is based on the financial information presented
in the Consolidated Financial Statements - Segment Note as updated in this Form
8-K (see Note (2)). Corporate allocations, income taxes and non-operating items
are discussed only on a consolidated basis.
Utility Operations
The following presentation sets forth the operating results for Electric
(inclusive of transmission activities) for fiscal year 2002 compared to 2001.
Subsequent to filing the Form 10-Q for the quarter ended March 31, 2003, the
Company changed the segment reporting for Utility Operations to disaggregate its
presentation of Electric and transmission activities ("Transmission"). Based on
this change, set forth below also is a presentation of the operating results for
Electric (without Transmission) and for Transmission, in each case for the
fiscal year 2001 compared to 2000.
Electric
The table below sets forth the operating results for Electric.
Year Ended December 31,
---------------------------------
2001 2000 Variance
--------------- -------------- --------------
(In thousands)
Operating revenues............................... $559,226 $538,683 $ 20,543
Less: Cost of energy............................. 162,884 132,244 30,640
Energy transfer........................... (21,999) (22,064) 65
--------------- -------------- --------------
Gross margin..................................... 418,341 428,503 (10,162)
--------------- -------------- --------------
Energy production costs.......................... 121,277 109,955 11,322
Transmission and distribution O&M................ 37,853 33,084 4,769
Customer related expense......................... 19,388 21,040 (1,652)
Administrative and general....................... 10,553 9,222 1,331
--------------- -------------- --------------
Total non-fuel O&M............................. 189,071 173,301 15,770
Corporate allocation............................. 59,084 49,684 9,400
Depreciation and amortization.................... 66,680 62,457 4,223
Taxes other than income taxes.................... 18,524 18,129 395
Income taxes..................................... 19,230 34,734 (15,504)
--------------- -------------- --------------
Total non-fuel operating expenses.............. 352,589 338,305 14,284
--------------- -------------- --------------
Operating income................................. $65,752 $90,198 $(24,446)
--------------- -------------- --------------
22
The following table shows electric revenues by customer class and average
customers:
Electric Revenues
Year Ended
December 31,
--------------------------------
2001 2000 Variance
-------------- -------------- --------------
(In thousands)
Residential.................. $ 187,600 $ 186,133 $ 1,467
Commercial................... 242,372 238,243 4,129
Industrial................... 82,752 79,671 3,081
Transmission................. 26,553 16,855 9,698
Other........................ 19,949 17,781 2,168
-------------- -------------- --------------
$ 559,226 $ 538,683 $ 20,543
============== ============== ==============
Average customers............ 377,589 368,506 9,083
============== ============== ==============
The following table shows electric sales by customer class:
Electric Sales
(Megawatt hours)
Year Ended
December 31,
--------------------------------
2001 2000 Variance
--------------- -------------- ---------------
(In thousands)
Residential............ 2,197,889 2,171,945 25,944
Commercial............. 3,213,208 3,133,996 79,212
Industrial............. 1,603,266 1,544,367 58,899
Other.................. 240,934 238,635 2,299
--------------- -------------- ---------------
7,255,297 7,088,943 166,354
=============== ============== ===============
Operating revenues increased $20.5 million or 3.8% for the period to
$559.2 million. Retail electricity delivery grew 2.3% to 7.3 million MWh in 2001
compared to 7.1 million MWh delivered in the prior year, resulting in increased
revenues of $8.9 million year-over-year. This volume increase was the result of
load growth from economic expansion in New Mexico. In addition, revenues from
third party use of the Company's transmission system increased $9.7 million as a
result of additional contracts from increased activity in the Western power
market. Revenues also benefited from a $1.1 million increase in revenue from
property leasing.
The gross margin, or operating revenues minus cost of energy sold,
decreased $10.2 million or 2.4% due to higher cost for the electricity sold to
retail customers resulting from increased use of higher cost generation. In
2001, the Company experienced outages at its coal and nuclear facilities, which
required it to increase its operations at Reeves Generating Station ("Reeves"),
one of the Company's gas generation facilities, which has a higher cost of
production. This decrease was partially offset by increased energy sales,
transmission revenues and property leasing revenue.
23
Total non-fuel O&M increased $15.8 million or 9.1%. Energy production
costs increased $11.3 million or 10.3% for the year. The increase is primarily
due to higher maintenance costs of $6.8 million in 2001 resulting from scheduled
and unscheduled outages at PVNGS, SJGS and Reeves, additional incentive bonuses
of $0.4 million at SJGS, and increased operations costs of $1.0 million for
generation at Reeves, one of the Company's gas generation facilities, which has
a higher cost of production than the Company's coal and nuclear facilities. This
increase was partially offset by lower maintenance costs of $1.1 million at Four
Corners as a result of decreased outage time. A significant unscheduled outage
occurred in the fall of 2001 at SJGS, which resulted in higher costs of $2.0
million in 2001. The Company took advantage of the outage to accelerate its
outage scheduled for the spring of 2002. As a result, maintenance costs and the
related lost market potential of the accelerated outage, was avoided in the
spring of 2002. Transmission and distribution costs increased $4.8 million or
14.4% primarily due to a non-recurring increase in maintenance to improve
reliability for the transmission and distribution systems. Customer related
expense decreased $1.7 million or 7.9% due to lower bad debt and collection
expense. By December 2000, the Company had resolved most of the problems
associated with implementing its new billing system. As a result, bad debt
expense was significantly lower in 2001. Administrative and general costs
increased $1.3 million or 14.4% for the period due to consulting expenses
focused on cost control and process improvement initiatives. Depreciation and
amortization increased $4.2 million or 6.8% due to a higher depreciable plant
base.
Electric (without Transmission)
The table below sets forth the operating results for Electric.
Year Ended December 31,
---------------------------------
2001 2000 Variance
--------------- -------------- --------------
(In thousands)
Operating revenues............................... $532,673 $521,828 $ 10,845
Less: Cost of energy............................. 189,055 156,334 32,721
Energy transfer........................... (21,999) (22,064) 65
--------------- -------------- --------------
Gross margin..................................... 365,617 387,558 (21,941)
--------------- -------------- --------------
Energy production costs.......................... 120,353 108,747 11,606
Distribution O&M................................. 20,712 18,780 1,932
Customer related expense......................... 19,388 21,040 (1,652)
Administrative and general....................... 8,398 7,198 1,200
--------------- -------------- --------------
Total non-fuel O&M............................. 168,851 155,765 13,086
Corporate allocation............................. 54,488 45,973 8,515
Depreciation and amortization.................... 59,352 54,429 4,923
Taxes other than income taxes.................... 16,272 15,526 746
Income taxes..................................... 13,788 32,867 (19,079)
--------------- -------------- --------------
Total non-fuel operating expenses.............. 312,751 304,560 8,191
--------------- -------------- --------------
Operating income................................. $52,866 $82,998 $(30,132)
--------------- -------------- --------------
24
The following table shows electric revenues by customer class and average
customers:
Electric Revenues
Year Ended
December 31,
--------------------------------
2001 2000 Variance
-------------- -------------- --------------
(In thousands)
Residential........... $ 187,600 $ 186,133 $ 1,467
Commercial............ 242,372 238,243 4,129
Industrial............ 82,752 79,671 3,081
Other................. 19,949 17,781 2,168
-------------- -------------- --------------
$ 532,673 $ 521,828 $ 10,845
============== ============== ==============
Average customers..... 377,589 368,506 9,083
============== ============== ==============
The following table shows electric sales by customer class:
Electric Sales
(Megawatt hours)
Year Ended
December 31,
--------------------------------
2001 2000 Variance
--------------- -------------- ---------------
(In thousands)
Residential............. 2,197,889 2,171,945 25,944
Commercial.............. 3,213,208 3,133,996 79,212
Industrial.............. 1,603,266 1,544,367 58,899
Other................... 240,934 238,635 2,299
--------------- -------------- ---------------
7,255,297 7,088,943 166,354
=============== ============== ===============
Operating revenues increased $10.8 million or 2.1% for the period to
$532.7 million. Retail electricity delivery grew 2.3% to 7.3 million MWh in 2001
compared to 7.1 million MWh delivered in the prior year, resulting in increased
revenues of $8.9 million year-over-year. This volume increase was the result of
load growth from economic expansion in New Mexico. Revenues also benefited from
a $1.1 million increase in revenue from property leasing.
The gross margin, or operating revenues minus cost of energy sold,
decreased $21.9 million or 5.7% due to higher cost for the electricity sold to
retail customers resulting from increased use of higher cost generation. In
2001, the Company experienced outages at its coal and nuclear facilities, which
required it to increase its operations at Reeves, one of the Company's gas
generation facilities, which has a higher cost of production. This decrease was
partially offset by increased energy sales, transmission revenues and property
leasing revenue. Electric exclusively purchases transmission services from
Transmission. These intercompany revenues and expenses are eliminated in the
consolidated results.
25
Total non-fuel O&M increased $13.1 million or 8.4%. Energy production
costs increased $11.6 million or 10.7% for the year. The increase is primarily
due to higher maintenance costs of $6.8 million in 2001 resulting from scheduled
and unscheduled outages at PVNGS, SJGS and Reeves, additional incentive bonuses
of $0.4 million at SJGS, and increased operations costs of $1.0 million for
generation at Reeves, one of the Company's gas generation facilities, which has
a higher cost of production than the Company's coal and nuclear facilities. This
increase was partially offset by lower maintenance costs of $1.1 million at Four
Corners as a result of decreased outage time. A significant unscheduled outage
occurred in the fall of 2001 at SJGS, which resulted in higher costs of $2.0
million in 2001. The Company took advantage of the outage to accelerate its
outage scheduled for the spring of 2002. As a result, maintenance costs and the
related lost market potential of the accelerated outage, was avoided in the
spring of 2002. Distribution costs increased $1.9 million or 10.3% primarily due
to a non-recurring increase in maintenance to improve reliability for the
transmission and distribution systems. Customer related expense decreased $1.7
million or 7.9% due to lower bad debt and collection expense. By December 2000,
the Company had resolved most of the problems associated with implementing its
new billing system. As a result, bad debt expense was significantly lower in
2001. Administrative and general costs increased $1.2 million or 16.7% for the
period due to consulting expenses focused on cost control and process
improvement initiatives. Depreciation and amortization increased $4.9 million or
9.1% due to a higher depreciable plant base. Taxes other than income taxes
increased $0.7 million or 4.8% due to the settlement of the Navajo possessory
interest tax on Four Corners.
Transmission
The table below sets forth the operating results for Transmission.
Year Ended December 31,
-----------------------------------
2001 2000 Variance
---------------- ---------------- --------------
(In thousands)
Operating revenues
External customers............................ $26,553 $16,855 $9,698
Intersegment revenues......................... 31,273 29,138 2,135
---------------- ---------------- --------------
Total revenues............................. 57,826 45,993 11,833
Cost of energy................................... 5,102 5,048 54
---------------- ---------------- --------------
Gross margin..................................... 52,724 40,945 11,779
---------------- ---------------- --------------
Energy production costs.......................... 924 1,208 (284)
Transmission O&M ................................ 17,141 14,304 2,837
Administrative and general....................... 2,155 2,024 131
---------------- ---------------- --------------
Total non-fuel O&M......................... 20,220 17,536 2,684
Corporate allocation............................. 4,596 3,711 885
Depreciation and amortization.................... 7,328 8,028 (700)
Taxes other than income taxes.................... 2,252 2,603 (351)
Income taxes..................................... 5,442 1,867 3,575
---------------- ---------------- --------------
Total non-fuel operating expenses.......... 39,838 33,745 6,093
---------------- ---------------- --------------
Operating income................................. $12,886 $ 7,200 $ 5,686
---------------- ---------------- --------------
Operating revenues increased $11.8 million or 25.7% and gross margin
increased $11.8 million or 28.8% primarily due to increased third party use of
the Company's transmission system as a result of additional contracts and sales
to Electric from increased activity in the Western power market.
26
Total non-fuel O&M increased $2.7 million or 15.3%. Transmission costs
increased $2.8 million or 19.8% primarily due to a non-recurring increase in
maintenance to improve reliability for the transmission and distribution
systems. Depreciation and amortization decreased $0.7 million due to a transfer
of certain plant to generation in anticipation of restructuring the electric
utility industry in New Mexico.
Gas
The table below sets forth the operating results for Gas.
Year Ended December 31,
----------------------------------
2001 2000 Variance
--------------- ---------------- ---------------
(In thousands)
Operating revenues............................... $385,418 $319,924 $ 65,494
Cost of energy................................... 251,296 195,334 55,962
--------------- ---------------- ---------------
Gross margin..................................... 134,122 124,590 9,532
--------------- ---------------- ---------------
Energy production costs.......................... 1,946 1,485 461
Distribution O&M................................. 31,064 27,206 3,858
Customer related expense......................... 19,814 19,164 650
Administrative and general....................... 6,736 3,880 2,856
--------------- ---------------- ---------------
Total non-fuel O&M............................. 59,560 51,735 7,825
Corporate allocation............................. 30,908 29,405 1,503
Depreciation and amortization.................... 20,362 16,132 4,230
Taxes other than income taxes.................... 6,768 6,728 40
Income taxes..................................... 1,867 3,762 (1,895)
--------------- ---------------- ---------------
Total non-fuel operating expenses.............. 119,465 107,762 11,703
--------------- ---------------- ---------------
Operating income................................. $14,657 $16,828 $(2,171)
--------------- ---------------- ---------------
The following table shows gas revenues by customer and average customers:
Gas Revenues
Year Ended
December 31,
--------------------------------
2001 2000 Variance
-------------- -------------- --------------
(In thousands)
Residential............... $ 232,321 $ 191,231 $41,090
Commercial................ 68,895 52,964 15,931
Industrial................ 27,519 24,206 3,313
Transportation*........... 20,188 14,163 6,025
Other..................... 36,495 37,360 (865)
-------------- -------------- --------------
$ 385,418 $ 319,924 $65,494
============== ============== ==============
Average customers......... 434,591 434,943 (352)
============== ============== ==============
27
The following table shows gas throughput by customer class:
Gas Throughput
Year Ended
December 31,
--------------------------------
2001 2000 Variance
-------------- --------------- --------------
(Thousands of decatherms)
Residential.............. 27,848 28,810 (962)
Commercial............... 10,421 9,859 562
Industrial............... 3,920 5,038 (1,118)
Transportation*.......... 51,395 44,871 6,524
Other.................... 4,355 6,426 (2,071)
-------------- --------------- --------------
97,939 95,004 2,935
============== =============== ==============
*Customer-owned gas.
Operating revenues increased $65.5 million or 20.5% for the period to
$385.4 million. The Company purchases natural gas in the open market and resells
it at cost to its distribution customers. As a result, increased gas revenues
driven by increased gas costs do not impact the Company's gross margin or
earnings. The revenue increase was driven primarily by a 17.6% increase in
average gas prices in the first half of 2001, resulting from increased market
demand. In addition, a 3.1% volume increase and a gas rate increase, which
became effective October 30, 2000 contributed to the increase. The gas rate
increase added $7.8 million of revenue. Transportation volume increased 14.5% or
$6.0 million. This growth was primarily attributed to gas transportation
customers whose increased demand was driven by the strong power market in the
Western United States during the first half of 2001. Approximately $28.1 million
of gas revenue in 2001 was attributable to sales to Electric and Wholesale.
The gross margin, or operating revenues minus cost of energy sold,
increased $9.5 million or 7.7%. This increase is due to the rate increase and
higher transportation volumes.
Total non-fuel O&M increased $7.8 million or 15.1%. Distribution costs
increased $3.9 million or 14.2% primarily due to a non-recurring increase in
maintenance to improve reliability for the transmission and distribution
systems, as the Company continues to focus on improving reliability and
effectiveness of its retail distribution system. Customer related expense
increased $0.7 million or 3.4% due to increased labor and expenses resulting
from upgrades to the call center and increased collection efforts, partially
offset by decreased bad debt expense as a result of improved bad debt controls.
Administrative and general costs increased $2.9 million or 73.6% due to
consulting expenses incurred in connection with cost control and process
improvement initiatives. Depreciation and amortization increased $4.2 million or
26.2% for the period primarily resulting from the retrofit of the distribution
system to make use of new technology which inspects the integrity of the system.
28
Wholesale
The table below sets forth the operating results for Wholesale.
Year Ended December 31,
-----------------------------------
2001 2000 Variance
--------------- --------------- ---------------
(In thousands)
Operating revenues............................... $1,304,284 $650,699 $653,585
Less: Cost of energy............................ 1,020,754 522,493 498,261
Energy transfer....................... 21,999 22,064 (65)
--------------- --------------- ---------------
Gross margin..................................... 261,531 106,142 155,389
--------------- --------------- ---------------
Energy production costs.......................... 29,309 28,458 851
Customer related expense......................... 821 5,341 (4,520)
Administrative and general....................... 4,748 4,537 211
--------------- --------------- ---------------
Total non-fuel O&M............................. 34,878 38,336 (3,458)
Corporate allocation............................. 4,042 2,917 1,125
Depreciation and amortization.................... 5,774 5,491 283
Taxes other than income taxes.................... 2,498 2,600 (102)
Income taxes..................................... 78,102 15,515 62,587
--------------- --------------- ---------------
Total non-fuel operating expenses.............. 125,294 64,859 60,435
--------------- --------------- ---------------
Operating income................................. $ 136,237 $ 41,283 $ 94,954
--------------- --------------- ---------------
The following table shows revenues by customer class:
Wholesale Revenues
Year Ended
December 31,
--------------------------------
2001 2000 Variance
-------------- -------------- --------------
(In thousands)
Long-term contracts......... $ 77,250 $ 87,731 $(10,481)
Other merchant sales........ 1,224,388 556,146 668,242
Other....................... 2,646 6,822 (4,176)
-------------- -------------- --------------
$1,304,284 $ 650,699 $ 653,585
============== ============== ==============
The following table shows sales by customer class:
Wholesale Sales
Year Ended
December 31,
--------------------------------
2001 2000 Variance
-------------- --------------- --------------
(Megawatt hours)
Long-term contracts.......... 1,463,031 330,003 1,133,028
Other merchant sales.......... 10,596,004 10,213,725 382,279
-------------- --------------- --------------
12,059,035 10,543,728 1,515,307
============== =============== ==============
29
A significant increase in regional wholesale electric prices occurred in
the first half of 2001 and the second half of 2000. This increase was caused by,
among other things, the power supply/demand imbalance in the Western United
States, a lack of generating assets to serve the market and increased natural
gas prices. The high wholesale prices seen in 2001 and 2000 did not recur in
2002. At the end of the second quarter of 2001, the market experienced declining
price levels. This trend continued in the last half of 2001. As a result, market
liquidity - the opportunity to buy and resell power profitably in the
marketplace - also declined reflecting the bankruptcy of a major market
participant and limited price volatility.
Operating revenues grew $653.6 million or 100.4% for the period to $1.3
billion. This increase in wholesale electricity sales primarily reflects the
strong regional wholesale electric prices in the first half of 2001. The Company
delivered wholesale (bulk) power of 12.1 million MWh of electricity in 2002,
compared to 10.5 million MWh in the prior period. The average price realized by
the Company increased to approximately $108 per MWh in 2001 compared to $62 per
MWh in 2000.
The gross margin, or operating revenues minus cost of energy sold,
increased $155.4 million or 146.4%. The Company's margin benefits significantly
from rising gas prices as most of the Company's generation portfolio is fueled
by stable priced fuel sources, such as coal and uranium. As the increase in gas
prices puts upward pressure on electricity prices, the profitability of the
Company's stable low-cost generation increases significantly. Margin also
benefited from the Company's power marketing activities. The Company buys and
then resells electricity in the market generating incremental margin by taking
advantage of price changes in the electricity sales market. In addition, the
Company also tailors electric deliveries for its wholesale customers creating
incremental margin opportunities. Generally, as market prices decline, marketing
volumes rise supporting margin levels in lower price electric markets. These
higher margins were partially offset by an unfavorable change in the
mark-to-market position of the marketing portfolio of $21.0 million
year-over-year ($25.8 million loss in 2001 versus $4.8 million loss in 2000) as
the Western power market deterioration in the latter half of 2001 resulted in a
reduction of the Company's merchant energy portfolio.
Total non-fuel O&M decreased $3.5 million or 9.0%. Energy production
costs increased $0.9 million or 3.0% for the year. The increase is primarily due
to higher maintenance costs of $1.1 million in 2001 resulting from scheduled and
unscheduled outages at PVNGS, SJGS and Reeves Generating Station ("Reeves").
Customer related expense decreased $4.5 million or 84.6% due to lower
year-over-year Wholesale business development costs due to significant costs
related to the acquisition of a long-term wholesale customer in 2000.
Avistar
In July 2001, the Board of Directors of Avistar decided to wind down all
unregulated operations except for Avistar's Reliadigm business unit, which
provides maintenance solutions and technologies to the electric power industry.
Avistar had previously divested itself of its Energy Partners business unit and
liquidated Axon Field Services and Pathways Integration. This divestiture was
largely in response to market disruptions caused by the California energy
crisis. In addition, the transfer of operation of the Sangre de Cristo Water
Company to the City of Santa Fe was completed in the third quarter of 2001. All
30
remaining non-Reliadigm investments were written-off with the exception of
Avistar's investment in Nth Power, an energy related venture capital fund. These
write-downs reflect the significant decline in the technology market and
bankruptcy of these investees. The Company recorded non-operating charges of
$13.1 million to reflect these activities and the impairment of its Avistar
investments.
Due to the cessation of much of Avistar's historic operations, business
activity declined significantly. Revenues decreased 30.8% for the period to $1.5
million. Operating losses for Avistar decreased from $4.6 million in 2000 to
$4.2 million in 2001 primarily due to decreased costs as a result of the
shutdown of certain operations. In January 2002, Avistar was transferred by way
of a dividend to Holding Company by PNM.
Corporate and Other
Corporate administrative and general costs, which represent costs that
are driven exclusively by corporate-level activities, increased $11.3 million or
14.0% for the period to $91.9 million. This increase was due to increased
pension and post-retirement benefits expense of $9.9 million and higher legal
costs of $0.8 million associated with routine business operations.
Consolidating Non-Operating
Other Income and Deductions
Other income decreased $14.1 million for the year. In 2000, the Company
recognized a gain of $13.8 million related to the settlement of a lawsuit.
Other deductions increased $55.3 million for the year. In 2001, the
Company recorded charges of $13.1 million to write-off certain permanently
impaired Avistar investments, $13.0 million of non-recoverable coal mine
decommissioning costs previously established as a regulatory asset,
non-recoverable regulatory costs of $11.1 million, a donation of $5.0 million to
the PNM Foundation and a charge of $18.0 million related to the Company's
terminated acquisition of Western Resources. In 2000, the Company recognized
gains of $4.5 million for the reversal of certain reserves associated with the
resolution of two gas rate claims and $2.4 million related to the Company's
hedge of certain non-qualified retirement plan trust assets. In addition, in
2000, the Company recorded charges of $12.5 million related to the Company's
terminated acquisition of Western Resources.
Income Taxes
The Company's consolidated income tax expense was $81.1 million in the
twelve months ended December 31, 2001, an increase of $6.7 million for the year.
This increase was due to higher earnings in 2001. The Company's effective income
tax rates for the years ended 2001 and 2000 were 35.02% and 42.41%,
respectively. In 2001, the Company determined that $6.6 million of valuation
allowances taken against certain income tax related regulatory assets were no
longer required due to changes in the evaluation of its regulatory strategy in
light of the holding company filing in May 2001. In 2000, when the allowance was
established, management believed these income-tax-related regulatory assets
would not be recoverable based on the probable regulatory outcome of industry
restructuring in New Mexico. Currently, management fully expects to recover
these costs in future rate cases, a situation that was not possible prior to the
31
delay of open access in New Mexico. Excluding the impact of the valuation
reserve changes, the Company's effective income tax rates for the years ended
2001 and 2000 were 37.85% and 38.67%, respectively. The decrease in the
effective rate was primarily due to the favorable tax treatment received on 2001
equity earnings from a passive investment.
NEW AND PROPOSED ACCOUNTING STANDARDS
EITF 02-3 "Issues Related to Accounting for Contracts Involved in Energy
Trading and Risk Management Activities", EITF 98-10 "Accounting for Contracts
Involved in Energy Trading and Risk Management Activities" and Statement of
Financial Accounting Standards No. 133 "Accounting for Derivative Instruments
and Hedging Activities" ("SFAS 133"). On October 25, 2002, the EITF reached a
final consensus on EITF 02-3 that rescinds EITF 98-10 and requires that all
energy contracts held for trading purposes be presented on a net margin basis in
the statement of earnings. The rescission of EITF 98-10 requires that energy
contracts which do not meet the definition of a derivative under SFAS 133 no
longer be marked to market and recognized in current earnings. As a result, all
contracts which were marked to market under EITF 98-10 and must now be accounted
for under the accrual method should be written back to cost with any difference
included as a cumulative effect of a change in accounting principle in the
period of adoption. This transition provision was effective January 1, 2003. The
rescission of EITF 98-10 did not have a material impact on the Company's
financial condition or results of operations as all contracts previously marked
to market under the definition provided in EITF 98-10 also met the definition of
a derivative under SFAS 133 and are properly recorded at fair value with gains
and losses recorded in earnings. The Company reviewed its energy contract
portfolio to determine whether its contracts meet the definition of trading
activities under EITF 02-3. As a result, the Company has reclassified those
contracts previously accounted for under EITF 98-10 to a net margin basis for
the fiscal years ended December 31, 2002, 2001 and 2000. The Company will not
report revenues and cost of energy sold on a net margin basis on a prospective
basis as a result of the application of EITF 02-3 as none of the Company's
marketing activities meet the definitions of trading activities as prescribed by
EITF 02-3.
The following table details wholesale electric revenues as reclassified
under EITF 02-3. Energy trading margin is included in Electric Operating
Revenues in the Statement of Earnings:
Year Ended December 31,
2002 2001 2000
------------- -------------- --------------
(In thousands)
Wholesale revenues............................. $76,226 $60,982 $80,207
Wholesale purchases (EITF 02-3 adjustment)..... (73,987) (89,351) (99,735)
------------- -------------- --------------
Energy trading margin.......................... $ 2,239 $ (28,369) $ (19,528)
============= ============== ==============
32
DISCLOSURE REGARDING FORWARD LOOKING STATEMENTS
Statements made in this filing and other documents the Company files with
the SEC that relate to future events or its expectations, projections,
estimates, intentions, goals, targets and strategies are made pursuant to the
Private Securities Litigation Reform Act of 1995. Readers are cautioned that all
forward-looking statements are based upon current expectations and estimates and
the Company assumes no obligation to update this information.
Because actual results may differ materially from those expressed or
implied by the forward-looking statements, the Company cautions readers not to
place undue reliance on these statements. Factors that could cause actual
results to differ, and that will affect the Company's future financial
condition, cash flow and operating results include interest rates, weather, fuel
costs, changes in supply and demand in the market for electric power, wholesale
power prices, market liquidity, the competitive environment in the electric and
natural gas industries, the performance of generating units and transmission
system, state and federal regulatory and legislative decisions and actions, the
outcome of legal proceedings and the performance of state, regional and national
economies. For a detailed discussion of the important factors that affect the
Company and that could cause actual results to differ from those expressed or
implied by the Company's forward-looking statements, please see "Management's
Discussion and Analysis of Financial Condition and Results of Operations" in the
Company's current and future Annual Reports on Form 10-K and Quarterly Reports
on Form 10-Q and also the Company's current and future Current Reports on Form
8-K, filed with the SEC.
(Intentionally left blank)
33
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEX
Page
Management's Responsibility for Financial Statements........................34
Report of Independent Auditors (PNM Resources, Inc.)........................36
Report of Independent Auditors (Public Service Company of New Mexico).......37
Financial Statements:
PNM Resources, Inc. and Subsidiaries
Consolidated Statements of Earnings..................................38
Consolidated Statements of Retained Earnings.........................39
Consolidated Balance Sheets..........................................40
Consolidated Statements of Cash Flows................................42
Consolidated Statements of Capitalization............................43
Consolidated Statements of Comprehensive Income/(Loss)...............44
Public Service Company of New Mexico
Consolidated Statements of Earnings..................................45
Consolidated Statements of Retained Earnings.........................46
Consolidated Balance Sheets..........................................47
Consolidated Statements of Cash Flows................................49
Consolidated Statements of Capitalization............................50
Consolidated Statements of Comprehensive Income/(Loss)...............51
Notes to Consolidated Financial Statements...............................52
Supplementary Data:
Quarterly Operating Results..............................................100
Comparative Operating Statistics.........................................101
Independent Auditors' Report.............................................103
Schedule I Condensed Financial Information of Parent Company.............106
Schedule II Valuation and Qualifying Accounts............................107
MANAGEMENT'S RESPONSIBILITY FOR FINANCIAL STATEMENTS
The accompanying financial statements of PNM Resources, Inc. and its
subsidiaries and Public Service Company of New Mexico and its subsidiaries, a
wholly owned subsidiary of PNM Resources, Inc., have been prepared in conformity
with accounting principles generally accepted in the United States of America.
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 PNM Resources,
34
Inc.'s and Public Service Company of New Mexico'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; and
programs to further timely communication and monitoring of policies, standards
and delegated authorities.
The Audit and Ethics Committee of the Board of Directors of PNM Resources, Inc.,
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 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.
35
REPORT OF INDEPENDENT AUDITORS
To the Board of Directors and Stockholders of
PNM Resources, Inc.
We have audited the accompanying consolidated balance sheets and consolidated
statements of capitalization of PNM Resources, Inc. and subsidiaries as of
December 31, 2002 and 2001, and the related consolidated statements of earnings,
retained earnings, comprehensive income (loss), and cash flows for each of the
three years in the period ended December 31, 2002. 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 of America. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether the financial
statements are free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in the financial
statements. An audit also includes assessing the accounting principles used and
significant estimates made by management, as well as evaluating the overall
financial statement presentation. We believe that our audits provide a
reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in all
material respects, the financial position of PNM Resources, Inc. and
subsidiaries as of December 31, 2002 and 2001, and results of their operations
and their cash flows for each of the three years in the period ended December
31, 2002, in conformity with accounting principles generally accepted in the
United States of America.
As discussed in Note 16 to the consolidated financial statements, the Company
adopted EITF 02-3 "Issues Involved in Accounting for Derivative Contracts Held
for Trading Purposes and Contracts Involved in Energy Trading and Risk
Management Activities," effective January 1, 2003.
As discussed in Note 2 to the consolidated financial statements, effective
January 1, 2003, the Company realigned its segments for financial reporting
purposes.
DELOITTE & TOUCHE LLP
Omaha, Nebraska
February 11, 2003
(June 5, 2003, as to Notes 2 and 16, as it relates to EITF 02-3)
36
REPORT OF INDEPENDENT AUDITORS
To the Board of Directors and Stockholder of
Public Service Company of New Mexico
We have audited the accompanying consolidated balance sheets and consolidated
statements of capitalization of Public Service Company of New Mexico and
subsidiaries as of December 31, 2002 and 2001, and the related consolidated
statements of earnings, retained earnings, comprehensive income (loss), and cash
flows for each of the three years in the period ended December 31, 2002. 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 of America. Those standards require that we plan and
perform the audit to obtain reasonable assurance about whether the financial
statements are free of material misstatement. An audit includes examining, on a
test basis, evidence supporting the amounts and disclosures in the financial
statements. An audit also includes assessing the accounting principles used and
significant estimates made by management, as well as evaluating the overall
financial statement presentation. We believe that our audits provide a
reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in all
material respects, the financial position of Public Service Company of New
Mexico and subsidiaries as of December 31, 2002 and 2001, and results of their
operations and their cash flows for each of the three years in the period ended
December 31, 2002, in conformity with accounting principles generally accepted
in the United States of America.
As discussed in Note 16 to the consolidated financial statements, the Company
adopted EITF 02-3 "Issues Involved in Accounting for Derivative Contracts Held
for Trading Purposes and Contracts Involved in Energy Trading and Risk
Management Activities," effective January 1, 2003.
As discussed in Note 2 to the consolidated financial statements, effective
January 1, 2003, the Company realigned its segments for financial reporting
purposes.
DELOITTE & TOUCHE LLP
Omaha, Nebraska
(June 5, 2003, as to Notes 2 and 16, as it relates to EITF 02-3)
37
PNM RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF EARNINGS
Year Ended December 31,
--------------------------------------------------
2002 2001 2000
--------------- --------------- ---------------
(In thousands, except per share amounts)
Operating Revenues: (notes 1 and 2)
Electric................................................. $ 821,487 $ 1,863,510 $ 1,189,457
Gas...................................................... 272,118 385,418 319,924
Unregulated businesses................................... 1,404 1,538 2,158
--------------- --------------- ---------------
Total operating revenues.............................. 1,095,009 2,250,466 1,511,539
--------------- --------------- ---------------
Operating Expenses:
Cost of energy sold...................................... 476,066 1,434,934 850,145
Administrative and general............................... 146,231 155,392 147,268
Energy production costs.................................. 149,528 152,455 139,894
Depreciation and amortization............................ 102,409 96,936 93,059
Transmission and distribution costs...................... 63,870 69,001 60,330
Taxes, other than income taxes........................... 34,244 30,302 34,405
Income taxes (note 1 and 8).............................. 20,887 88,769 53,964
--------------- --------------- ---------------
Total operating expenses.............................. 993,235 2,027,789 1,379,065
--------------- --------------- ---------------
Operating income...................................... 101,774 222,677 132,474
--------------- --------------- ---------------
Other Income and Deductions:
Other income............................................. 48,360 52,147 66,246
Other deductions......................................... (12,306) (67,257) (11,950)
Income tax (expense) benefit (notes 1 and 8)............ (12,144) 7,706 (20,382)
--------------- --------------- ---------------
Net other income and deductions....................... 23,910 (7,404) 33,914
--------------- --------------- ---------------
Earnings before interest charges...................... 125,684 215,273 166,388
--------------- --------------- ---------------
Interest Charges:
Interest on long-term debt (note 4)...................... 56,409 62,716 62,823
Other interest charges................................... 5,003 2,124 2,619
--------------- --------------- ---------------
Net interest charges.................................. 61,412 64,840 65,442
--------------- --------------- ---------------
Net Earnings............................................... 64,272 150,433 100,946
Preferred Stock Dividend Requirements...................... 586 586 586
--------------- --------------- ---------------
Net Earnings Applicable to Common Stock.................... $ 63,686 $ 149,847 $ 100,360
=============== =============== ===============
Net Earnings per Share of Common Stock (Basic) (note 7).... $ 1.63 $ 3.83 $ 2.54
=============== =============== ===============
Net Earnings per Share of Common Stock (Diluted) (note 7).. $ 1.61 $ 3.77 $ 2.53
=============== =============== ===============
Dividends Paid per Share of Common Stock................... $ 0.86 $ 0.80 $ 0.80
=============== =============== ===============
The accompanying notes are an integral part of these
financial statements.
38
PNM RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS
Year Ended December 31,
--------------------------------------------------
2002 2001 2000
--------------- --------------- ---------------
(In thousands)
Balance at Beginning of Year............................. $ 415,388 $ 296,843 $ 227,828
Net earnings before preferred stock dividends.......... 64,272 150,433 100,946
Dividends (note 4):
Cumulative preferred stock.......................... (586) (586) (586)
Common stock........................................ (34,423) (31,302) (31,345)
--------------- --------------- ---------------
Balance at End of Year................................... $ 444,651 $ 415,388 $ 296,843
=============== =============== ===============
The accompanying notes are an integral part of these
financial statements.
39
PNM RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
As of December 31,
-------------------------------
2002 2001
--------------- -------------
(In thousands)
Utility Plant: (notes 1, 11 and 12)
Electric plant in service................................................... $2,301,673 $2,117,947
Gas plant in service........................................................ 615,907 575,350
Common plant in service and plant held for future use....................... 79,987 45,223
--------------- -------------
2,997,567 2,738,520
Less accumulated depreciation and amortization.............................. 1,330,376 1,251,801
--------------- -------------
1,667,191 1,486,719
Construction work in progress............................................... 173,248 246,278
Nuclear fuel, net of accumulated amortization of $16,568 and $16,954........ 26,832 26,940
--------------- -------------
Net utility plant........................................................ 1,867,271 1,759,937
--------------- -------------
Other Property and Investments:
Other investments (notes 1, 6 and 12)....................................... 442,704 552,453
Non-utility property, net of accumulated depreciation of $1,750 and $1,580.. 1,528 1,784
--------------- -------------
Total other property and investments..................................... 444,232 554,237
--------------- -------------
Current Assets:
Cash and cash equivalents................................................... 3,702 28,408
Accounts receivables, net of allowance for uncollectible accounts
of $15,575 and $18,025.................................................. 76,850 84,620
Unbilled revenues (note 1).................................................. 49,079 62,377
Other receivables........................................................... 47,122 51,883
Inventories (note 1)........................................................ 37,230 36,483
Regulatory assets (note 3).................................................. 24,027 10,473
Short-term investments (note 1)............................................. 79,630 45,111
Other current assets........................................................ 32,753 33,243
--------------- -------------
Total current assets..................................................... 350,393 352,598
--------------- -------------
Deferred charges:
Regulatory assets (note 3).................................................. 196,283 195,367
Prepaid retirement cost (note 9)............................................ 39,665 18,273
Other deferred charges...................................................... 129,063 33,376
--------------- -------------
Total deferred charges................................................... 365,011 247,016
--------------- -------------
$3,026,907 $2,913,788
=============== =============
The accompanying notes are an integral part of these
financial statements.
40
PNM RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
CAPITALIZATION AND LIABILITIES
As of December 31,
-------------------------------
2002 2001
--------------- --------------
(In thousands)
Capitalization:
Common stockholders' equity:
Common stock outstanding--39,118 shares, no par value (note 4)........... $ 624,119 $625,632
Accumulated other comprehensive loss, net of tax......................... (94,721) (28,996)
Retained earnings........................................................ 444,651 415,388
--------------- --------------
Total common stockholders' equity..................................... 974,049 1,012,024
Minority interest (notes 1 and 5).......................................... 11,760 11,652
Cumulative preferred stock without mandatory redemption
requirements (note 4).................................................... 12,800 12,800
Long-term debt (note 4).................................................... 980,092 953,884
--------------- --------------
Total capitalization.................................................... 1,978,701 1,990,360
--------------- --------------
Current Liabilities:
Short-term debt............................................................ 150,000 35,000
Accounts payable........................................................... 97,968 76,141
Accrued interest and taxes (notes 1 and 8)................................. 46,189 72,022
Other current liabilities.................................................. 99,019 149,454
--------------- --------------
Total current liabilities............................................... 393,176 332,617
--------------- --------------
Deferred Credits:
Accumulated deferred income taxes (notes 1 and 8).......................... 125,595 120,153
Accumulated deferred investment tax credits (notes 1 and 8)................ 41,583 44,714
Regulatory liabilities (note 3)............................................ 52,019 54,295
Regulatory liabilities related to accumulated deferred income tax (note 3). 14,137 14,163
Accrued post-retirement benefit cost (note 9).............................. 17,335 14,929
Other deferred credits (note 13)........................................... 404,361 342,557
--------------- --------------
Total deferred credits.................................................. 655,030 590,811
--------------- --------------
Commitments and Contingencies (note 12)...................................... - -
--------------- --------------
$3,026,907 $2,913,788
=============== ==============
The accompanying notes are an integral part of these
financial statements.
41
PNM RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31,
----------------------------------------------
2002 2001 2000
-------------- -------------- --------------
Cash Flows From Operating Activities: (In thousands)
Net earnings...................................................... $ 64, 272 $150,433 $100,946
Adjustments to reconcile net earnings to net cash flows
from operating activities:
Depreciation and amortization................................. 115,415 106,768 103,829
Accumulated deferred investment tax credit.................... (3,131) (3,139) (3,143)
Accumulated deferred income tax............................... 47,269 (32,927) 21,215
Asset write-offs.............................................. 4,817 24,079 -
Write-off Avistar investments................................. - 12,417 -
Non-recurring merger costs.................................... (2,436) 17,975 6,700
Net unrealized losses on trading and investment contracts..... (29,513) 26,172 370
Wholesale credit reserve...................................... - (5,406) 8,456
Other, net.................................................... 2,083 (4,297) (330)
Changes in certain assets and liabilities:
Accounts receivables........................................ 10,220 92,990 (90,680)
Other assets................................................ (52,655) 32,481 (32,444)
Accounts payable............................................ 23,660 (137,073) 107,346
Other liabilities........................................... (82,750) 46,873 17,250
-------------- -------------- --------------
Net cash flows provided by operating activities........... 97,251 327,346 239,515
-------------- -------------- --------------
Cash Flows From Investing Activities:
Utility plant additions........................................... (240,225) (264,844) (146,878)
Redemption of short-term investments.............................. 76,633 - -
Return of principal PVNGS lessor notes............................ 17,531 16,674 16,668
Merger acquisition costs.......................................... - (11,567) (6,700)
Short-term and long-term investments.............................. - (150,000) -
Other............................................................. (54,366) 2,723 (20,590)
-------------- -------------- --------------
Net cash flows used for investing activities.............. (200,427) (407,014) (157,500)
-------------- -------------- --------------
Cash Flows From Financing Activities:
Borrowings (note 4)............................................... 115,000 35,000 -
Repayments (note 4)............................................... - - (32,800)
Exercise of employee stock options (note 10)...................... (2,412) (2,179) (1,232)
Common stock repurchase (note 4).................................. - - (27,867)
Dividends paid.................................................... (34,226) (31,876) (32,265)
Other............................................................. 108 (560) (559)
-------------- -------------- --------------
Net cash flows provided by (used for) financing activities 78,470 385 (94,723)
-------------- -------------- --------------
Decrease in Cash and Cash Equivalents............................... (24,706) (79,283) (12,708)
Beginning of Year................................................... 28,408 107,691 120,399
-------------- -------------- --------------
End of Year......................................................... $ 3,702 $ 28,408 $ 107,691
============== ============== ==============
Supplemental cash flow disclosures:
Interest paid, net of capitalized interest........................ $ 53,041 $ 62,216 $ 64,045
============== ============== ==============
Income taxes paid, net............................................ $ 13,541 $ 72,146 $ 50,480
============== ============== ==============
Long-term debt assumed for transmission line...................... $ 26,152 $ - $ -
============== ============== ==============
The accompanying notes are an integral part of
these financial statements.
42
PNM RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CAPITALIZATION
As of December 31,
---------------------------------
2002 2001
--------------- --------------
(In thousands)
Common Stock Equity:
Common Stock, no par value (note 4)................................... $ 624,119 $ 625,632
Accumulated other comprehensive income, net of tax.................... (94,721) (28,996)
Retained earnings..................................................... 444,651 415,388
--------------- --------------
Total common stock equity......................................... 974,049 1,012,024
--------------- --------------
Minority Interest (notes 1 and 5)......................................... 11,760 11,652
--------------- --------------
Cumulative Preferred Stock: (note 4)
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, 2002 were 128,000................................ 12,800 12,800
--------------- --------------
Long-Term Debt: (note 4)
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 11,500
--------------- --------------
Total Senior Unsecured Notes, Pollution Control Revenue Bonds.... 474,845 474,845
--------------- --------------
Senior Unsecured Notes:
7.10% due 2005................................................ 268,420 268,420
7.50% due 2018................................................ 100,025 100,025
EIP debt due 2003-2012............................................... 26,152 -
Other, including unamortized discounts............................... (350) (406)
--------------- --------------
Total long-term debt......................................... 980,092 953,884
--------------- --------------
Total Capitalization...................................................... $ 1,978,701 $ 1,990,360
=============== ==============
The accompanying notes are an integral part of these
financial statements.
43
PNM RESOURCES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Year Ended December 31,
--------------------------------------------
2002 2001 2000
------------- -------------- -------------
(In thousands)
Net Earnings Before Preferred Stock Dividends.......................... $ 64,272 $150,433 $100,946
------------- -------------- -------------
Other Comprehensive Income (Loss), net of tax:
Unrealized gain (loss) on securities:
Unrealized holding gains arising during the period............... 1,303 70 2,508
Reclassification adjustment for losses included in net income.... (919) (526) (4,887)
Minimum pension liability adjustment................................. (55,061) (28,858) -
Mark-to-market adjustment for certain derivative transactions
Initial implementation of SFAS 133 designated cash flow hedges... - 6,148 -
Change in fair market value of designated cash flow hedges....... (10,361) 345 -
Reclassification adjustment for losses included in net income.... (687) (6,148) -
------------- -------------- -------------
Total Other Comprehensive Loss......................................... (65,725) (28,969) (2,379)
------------- -------------- -------------
Total Comprehensive Income (Loss)...................................... $(1,453) $121,464 $ 98,567
============= ============== =============
The accompanying notes are an integral part of these
financial statements.
44
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF EARNINGS
Year Ended December 31,
--------------------------------------------------
2002 2001 2000
--------------- --------------- ---------------
(In thousands, except per share amounts)
Operating Revenues: (notes 1 and 2)
Electric............................................ $ 821,487 $1,863,510 $1,189,457
Gas................................................. 272,118 385,418 319,924
Unregulated businesses.............................. - 1,538 2,158
--------------- --------------- ---------------
Total operating revenues......................... 1,093,605 2,250,466 1,511,539
--------------- --------------- ---------------
Operating Expenses:
Cost of energy sold................................. 475,256 1,434,934 850,145
Administrative and general.......................... 140,500 155,392 147,268
Energy production costs............................. 149,528 152,455 139,894
Depreciation and amortization....................... 101,689 96,936 93,059
Transmission and distribution costs................. 63,870 69,001 60,330
Taxes, other than income taxes...................... 31,333 30,302 34,405
Income taxes (note 1 and 8)......................... 22,774 88,769 53,964
--------------- --------------- ---------------
Total operating expenses......................... 984,950 2,027,789 1,379,065
--------------- --------------- ---------------
Operating income................................. 108,655 222,677 132,474
--------------- --------------- ---------------
Other Income and Deductions:
Other income........................................ 40,446 52,147 66,246
Other deductions.................................... (15,059) (67,257) (11,950)
Income tax (expense) benefit (notes 1 and 8)....... (10,096) 7,706 (20,382)
--------------- --------------- ---------------
Net other income and deductions.................. 15,291 (7,404) 33,914
--------------- --------------- ---------------
Earnings before interest charges................. 123,946 215,273 166,388
--------------- --------------- ---------------
Interest Charges:
Interest on long-term debt (note 4)................. 56,409 62,716 62,823
Other interest charges.............................. 5,321 2,124 2,619
--------------- --------------- ---------------
Net interest charges............................. 61,730 64,840 65,442
--------------- --------------- ---------------
Net Earnings Before Preferred Stock Dividends......... 62,216 150,433 100,946
Preferred Stock Dividend Requirements................. 586 586 586
--------------- --------------- ---------------
Net Earnings.......................................... $ 61,630 $ 149,847 $ 100,360
=============== =============== ===============
See disclosures regarding Public Service
Company of New Mexico and subsidiaries included in the
notes to the consolidated financial statements.
45
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS
Year Ended December 31,
--------------------------------------------------
2002 2001 2000
--------------- --------------- ---------------
(In thousands)
Balance at Beginning of Year......................... $288,388 $296,843 $227,828
Net earnings before preferred stock dividends...... 62,216 150,433 100,946
Dividends (note 4):
Cumulative preferred stock...................... (586) (586) (586)
Common stock.................................... - (31,302) (31,345)
Dividends to Parent (note 4):
Assets.......................................... (34,880) - -
Cash............................................ (58,981) (127,000) -
--------------- --------------- ---------------
Balance at End of Year............................... $256,157 $288,388 $296,843
=============== =============== ===============
See disclosures regarding Public Service
Company of New Mexico and subsidiaries included in the
notes to the consolidated financial statements.
46
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
As of December 31,
-------------------------------
2002 2001
-------------- ---------------
(In thousands)
Utility Plant: (notes 1, 11 and 12)
Electric plant in service................................................... $2,301,048 $2,117,947
Gas plant in service........................................................ 615,907 575,350
Common plant in service and plant held for future use....................... 18,137 45,223
-------------- ---------------
2,935,092 2,738,520
Less accumulated depreciation and amortization.............................. 1,326,286 1,251,801
-------------- ---------------
1,608,806 1,486,719
Construction work in progress............................................... 159,435 246,278
Nuclear fuel, net of accumulated amortization of $16,568 and $16,954........ 26,832 26,940
-------------- ---------------
Net utility plant........................................................ 1,795,073 1,759,937
-------------- ---------------
Other Property and Investments:
Other investments (notes 1, 6 and 12)....................................... 428,823 446,784
Non-utility property, net of accumulated depreciation of $2,000 and $1,580.. 966 1,784
-------------- ---------------
Total other property and investments..................................... 429,789 448,568
-------------- ---------------
Current Assets:
Cash and cash equivalents................................................... 3,094 17,028
Accounts receivables, net of allowance for uncollectible accounts
of $15,575 and $18,025................................................. 76,850 84,620
Unbilled revenue (note 1)................................................... 49,079 62,377
Intercompany receivable..................................................... 4,593 -
Other receivables........................................................... 46,853 51,883
Inventories (note 1)........................................................ 37,228 36,483
Regulatory assets (note 3).................................................. 24,027 10,473
Short-term investments (note 1)............................................. - 45,111
Other current assets........................................................ 22,872 23,292
-------------- ---------------
Total current assets..................................................... 264,596 331,267
-------------- ---------------
Deferred charges:
Regulatory assets (note 3).................................................. 196,242 195,367
Prepaid retirement cost (note 9)............................................ 39,665 18,273
Other deferred charges...................................................... 129,083 33,376
-------------- ---------------
Total deferred charges................................................... 364,990 247,016
-------------- ---------------
$2,854,448 $2,786,788
============== ===============
See disclosures regarding Public Service
Company of New Mexico and subsidiaries included in
the notes to the consolidated financial statements.
47
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
CAPITALIZATION AND LIABILITIES
As of December 31,
---------------------------------
2002 2001
---------------- ---------------
(In thousands)
Capitalization:
Common Stockholders' Equity:
Common stock outstanding - 39,118 shares (note 4)........................ $ 195,589 $ 195,589
Paid-in capital.......................................................... 430,043 430,043
Accumulated other comprehensive loss, net of tax (note 3)................ (94,130) (28,996)
Retained earnings........................................................ 256,157 288,388
---------------- ---------------
Total common stockholders' equity..................................... 787,659 885,024
Minority interest (notes 1 and 5).......................................... 11,760 11,652
Cumulative preferred stock without mandatory redemption
requirements (note 4).................................................... 12,800 12,800
Long-term debt (note 4).................................................... 953,940 953,884
---------------- ---------------
Total capitalization.................................................... 1,766,159 1,863,360
---------------- ---------------
Current Liabilities:
Short-term debt............................................................ 150,000 35,000
Intercompany debt.......................................................... 28,436 -
Accounts payable........................................................... 95,714 76,141
Intercompany accounts payable.............................................. 34,468 -
Accrued interest and taxes (notes 1 and 8)................................. 36,450 72,022
Other current liabilities.................................................. 87,701 149,454
---------------- ---------------
Total current liabilities............................................... 432,769 332,617
---------------- ---------------
Deferred Credits:
Accumulated deferred income taxes (notes 1 and 8).......................... 128,383 120,153
Accumulated deferred investment tax credits (notes 1 and 8)................ 41,583 44,714
Regulatory liabilities (note 3)............................................ 52,019 54,295
Regulatory liabilities related to accumulated deferred income tax (note 3). 14,137 14,163
Accrued post-retirement benefit cost (note 9).............................. 17,335 14,929
Other deferred credits (note 13)........................................... 402,063 342,557
---------------- ---------------
Total deferred credits.................................................. 655,520 590,811
---------------- ---------------
Commitments and Contingencies (note 12)...................................... - -
---------------- ---------------
$ 2,854,448 $2,786,788
================ ===============
See disclosures regarding Public Service
Company of New Mexico and subsidiaries included in the
notes to the consolidated financial statements.
48
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
Year Ended December 31,
----------------------------------------------
2002 2001 2000
-------------- -------------- --------------
Cash Flows From Operating Activities: (In thousands)
Net earnings before preferred stock dividends........................... $ 62,216 $150,433 $100,946
Adjustments to reconcile net earnings to net cash flows
from operating activities:
Depreciation and amortization....................................... 114,695 106,768 103,829
Accumulated deferred investment tax credit.......................... (3,131) (3,139) (3,143)
Accumulated deferred income tax..................................... 49,338 (32,927) 21,215
Asset write-offs.................................................... 4,817 24,079 -
Write-off Avistar investments....................................... - 12,417 -
Non-recurring merger costs.......................................... (2,436) 17,975 6,700
Net unrealized (gains) losses on trading and investment contracts... (29,513) 26,172 370
Wholesale credit reserve............................................ - (5,406) 8,456
Other, net.......................................................... 3,924 (4,297) (330)
Changes in certain assets and liabilities:
Accounts receivables.............................................. 10,220 92,990 (90,680)
Other assets...................................................... (72,293) 42,432 (32,444)
Accounts payable.................................................. 19,573 (137,073) 107,346
Other liabilities................................................. (96,430) 46,873 17,250
-------------- -------------- --------------
Net cash flows provided by operating activities............. 60,980 337,297 239,515
-------------- -------------- --------------
Cash Flows From Investing Activities:
Utility plant additions................................................. (219,821) (264,844) (146,878)
Redemption of short-term investments.................................... 45,621 - -
Return of principal PVNGS lessor notes.................................. 17,531 16,674 16,668
Merger acquisition costs................................................ - (11,567) (6,700)
Short-term and long-term investments.................................... - (45,000) -
Other................................................................... (32,097) 3,392 (20,590)
-------------- -------------- --------------
Net cash flows used for investing activities................ (188,766) (301,345) (157,500)
-------------- -------------- --------------
Cash Flows From Financing Activities:
Borrowings (note 4)..................................................... 115,000 35,000 -
Repayments (note 4)..................................................... - - (32,800)
Exercise of employee stock options (note 10)............................ - (2,179) (1,232)
Common stock repurchase (note 4)........................................ - - (27,867)
Dividends paid.......................................................... (59,567) (158,876) (32,265)
Other................................................................... 108 (560) (559)
Change in intercompany accounts......................................... 58,311 - -
-------------- -------------- --------------
Net cash flows provided by (used for) financing activities.. 113,852 (126,615) (94,723)
-------------- -------------- --------------
Decrease in Cash and Cash Equivalents..................................... (13,934) (90,663) (12,708)
Beginning of Year......................................................... 17,028 107,691 120,399
-------------- -------------- --------------
End of Year............................................................... $ 3,094 $ 17,028 $107,691
============== ============== ==============
Supplemental cash flow disclosures:
Interest paid, net of capitalized interest.............................. $ 53,350 $ 62,216 $ 64,045
============== ============== ==============
Income taxes paid, net.................................................. $ 9,901 $ 72,146 $ 50,480
============== ============== ==============
Non-cash dividends to parent............................................ $ 34,880 $ - $ -
============== ============== ==============
See disclosures regarding Public Service
Company of New Mexico and subsidiaries included in
the notes to the consolidated financial statements.
49
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CAPITALIZATION
As of December 31,
---------------------------------
2002 2001
--------------- ---------------
(In thousands)
Common Stock Equity:
Common stock outstanding, par value $5 per share (note 4)............ $ 195,589 $ 195,589
Paid-in capital...................................................... 430,043 430,043
Accumulated other comprehensive income, net of tax................... (94,130) (28,996)
Retained earnings.................................................... 256,157 288,388
--------------- --------------
Total equity..................................................... 787,659 885,024
--------------- --------------
Minority Interest (notes 1 and 5)........................................ 11,760 11,652
--------------- --------------
Cumulative Preferred Stock: (note 4)
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, 2002 were 128,000............................... 12,800 12,800
--------------- --------------
Long-Term Debt: (note 4)
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 11,500
--------------- --------------
Total Senior Unsecured Notes, Pollution Control Revenue Bonds... 474,845 474,845
--------------- --------------
Senior Unsecured Notes:
7.10% due 2005............................................... 268,420 268,420
7.50% due 2018............................................... 100,025 100,025
Other, including unamortized discounts.............................. (350) (406)
--------------- --------------
Total long-term debt........................................ 953,940 953,884
--------------- --------------
Total Capitalization..................................................... $ 1,766,159 $ 1,863,360
=============== ==============
See disclosures regarding Public Service
Company of New Mexico and subsidiaries included in the
notes to the consolidated financial statements.
50
PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Year Ended December 31,
--------------------------------------------
2002 2001 2000
------------- -------------- -------------
(In thousands)
Net Earnings before preferred stock dividends....................... $62,216 $150,433 $100,946
------------- -------------- -------------
Other Comprehensive Income (Loss), net of tax:
Unrealized gain (loss) on securities:
Unrealized holding gains arising from the period.............. 861 70 2,508
Reclassification adjustment for gains included in net income.. (919) (526) (4,887)
Minimum pension liability adjustment.............................. (55,061) (28,858) -
Mark-to-market adjustment for certain derivative transactions
Initial implementation of SFAS 133 designated cash flow hedges - 6,148 -
Change in fair market value of designated cash flow hedges.... (9,328) 345 -
Reclassification adjustment for losses included in net income. (687) (6,148) -
------------- -------------- -------------
Total Other Comprehensive Loss...................................... (65,134) (28,969) (2,379)
------------- -------------- -------------
Total Comprehensive Income (Loss)................................... $(2,918) $121,464 $ 98,567
============= ============== =============
See disclosures regarding Public Service
Company of New Mexico and subsidiaries included in the
notes to the consolidated financial statements.
51
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2002, 2001 and 2000
(1) Summary of the Business and Significant Accounting Policies
Nature of Business
PNM Resources, Inc. (the "Holding Company") is an investor-owned holding
company of energy and energy related businesses. Its principal subsidiary,
Public Service Company of New Mexico ("PNM"), is an integrated public utility
primarily engaged in the generation, transmission, distribution and sale and
marketing of electricity; transmission, distribution and sale of natural gas
within the State of New Mexico and the sale and marketing of electricity in the
Western United States. The Holding Company and its subsidiaries, including PNM,
are herein after referred to as the "Company". In addition, the Company provides
energy and utility related services under its wholly-owned subsidiary, Avistar,
Inc. ("Avistar").
Upon the completion on December 31, 2001, of a one-for-one share exchange
between PNM and the Holding Company, the Holding Company became the parent
company of PNM. Prior to the share exchange, the Holding Company had existed as
a subsidiary of PNM. The new parent company began trading on the New York Stock
Exchange under the same PNM symbol beginning on December 31, 2001.
Presentation
The Notes to Consolidated Financial Statements of the Company are
presented on a combined basis. The Holding Company assumed substantially all of
the corporate activities of PNM on December 31, 2001. These activities are
billed to PNM on a cost basis to the extent they are for the corporate
management of PNM and are allocated to the operating segments. In January 2002,
Avistar and certain inactive subsidiaries of PNM were transferred by way of a
dividend to the Holding Company pursuant to an order from the New Mexico Public
Regulation Commission ("PRC"). Readers of the Notes to Consolidated Financial
Statements should assume that the information presented applies to the
consolidated results of operations and financial position of both the Holding
Company and its subsidiaries and PNM, except where the context or references
clearly indicate otherwise. Discussions regarding specific contractual
obligations generally reference the company that is legally obligated. In the
case of contractual obligations of PNM, these obligations are consolidated with
the Holding Company and its subsidiaries under generally accepted accounting
principles ("GAAP"). Broader operational discussions refer to the Company.
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").
52
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
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 FERC, and the PRC and
its predecessor. These "regulatory assets" and "regulatory liabilities" are
enumerated and discussed in Note 3.
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
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 Statement of
Financial Accounting Standards No. 101, Accounting for the Discontinuation of
Application of FASB Statement No. 71" ("SFAS 101"). The Company evaluates its
regulatory assets under Statement of Financial Accounting Standards No. 144,
"Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to
be Disposed of" ("SFAS 144"). In 2000, the Company determined certain stranded
costs would not be recovered and recorded a charge to earnings for these amounts
recorded as stranded cost assets.
Principles of Consolidation
The consolidated financial statements include the accounts of the Company
and subsidiaries in which it owns a majority voting interest or meets the
criteria of Emerging Issues Task Force ("EITF") 90-15, "Impact of
Non-Substantive Lessors, Residual Value Guarantees and Other Provisions in
Leasing Transactions." All significant intercompany transactions and balances
have been eliminated. There were no intercompany transactions between the
Holding Company and PNM in 2001 and 2000, except the dividend, consolidation of
PVNGS capital trust and minority interest described in Note 5.
Financial Statement Preparation
The preparation of financial statements in conformity with accounting
principles generally accepted in the United States 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.
Cash and Cash Equivalents
All liquid investments with maturities of three months or less at the
date of purchase are considered cash equivalents.
53
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Utility Plant
Utility plant, with the exception of Palo Verde Nuclear Generating
Station ("PVNGS") Unit 3, a portion San Juan Generating Station ("SJGS") Unit 4
and PNM'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. In 1989, PVNGS Unit 3 and a portion of SJGS Unit 4 were
excluded from New Mexico rate base. As a result, PNM wrote-down $17.4 million of
its carrying cost related to these assets. In 1993, PNM announced specific
actions determined to be necessary in order to accelerate PNM's preparation for
the competitive electric energy market. As part of this announcement, PNM stated
its intention to attempt to sell PVNGS Unit 3. As a result, PNM wrote-down PVNGS
Unit 3 by $181.3 million based on the estimated net realizable value of the
asset. Since that time, PNM has decided not to sell PVNGS Unit 3. In connection
with a rate reduction in 1994, PNM wrote down $131.6 million of its owned
interest in Units 1 and 2.
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 regulated property
in the normal course of business are credited or charged to the accumulated
provision for depreciation.
Allowance For Funds Used During Construction ("AFUDC")
The calculation of AFUDC is only permitted if a rate order exists that
provides recovery. AFUDC uses a weighted average cost of capital. PNM did not
calculate AFUDC on construction projects in 2002, 2001 or 2000.
Capitalized Interest
SFAS 34, "Capitalization of Interest Costs" requires that interest cost
be capitalized as part of the historical cost of acquiring certain assets and is
calculated using only the cost of borrowing. Under GAAP, interest can only be
capitalized on non-SFAS 71 assets. PNM capitalizes interest on its generation
projects not included in rate base that are under construction in which ground
has been broken for the project, i.e. construction activities are underway. The
interest cost to be capitalized is theoretically that portion of interest
expense that could have been avoided if construction expenditures were not made.
The rate used for capitalization is the rate for borrowings specific to the
project. If there are no specific borrowings, the weighted average borrowing
rate for the Company is used. PNM has not borrowed any funds specifically for
any projects; therefore interest is being capitalized at the overall weighted
average borrowing rate of 6.6%. PNM's capitalized interest was $6.4 million in
2002. No interest was capitalized in 2001 or 2000.
54
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Inventory
Inventory consists principally of materials and supplies, natural gas
held in storage for eventual resale, and coal held for use in electric
generation.
Generally, materials and supplies include the costs of transmission,
distribution and generating plant materials. Materials and supplies are charged
to inventory when purchased and are expensed or capitalized as appropriate when
issued. Materials and supplies are valued using an average costing method.
Obsolete materials and supplies are immediately expensed when identified.
Gas in underground storage is valued using a weighted-average inventory
method. Withdrawals are charged to sales service customers through the Purchased
Gas Adjustment Clause ("PGAC"). Adjustments to gas in underground storage due to
migration are charged to the PGAC and are based on a PRC pre-approved percentage
of injections.
Coal is valued using a rolling weighted average costing method that is
updated based on the current period cost per tons. Periodic aerial surveys are
performed and any necessary adjustments are expensed as identified.
Inventories consisted of the following at December 31, (in thousands).
2002 2001
------------- ------------
Coal.............................. $12,678 $12,960
Gas in underground storage........ 2,001 3,664
Materials and supplies............ 22,551 19,859
------------- ------------
$37,230 $36,483
============= ============
Investments
The Company's investments are comprised of U.S., state, and municipal
government obligations and corporate securities. Investments with maturities of
less than one year are considered short-term and are carried at fair value. All
investments are held in the Company's name and are in the custody of major
financial institutions. The specific identification method is used to determine
the cost of securities disposed of, with realized gains and losses reflected in
other income and expense. At December 31, 2002, all of the Company's investments
were classified as available for sale. Unrealized gains and losses on these
investments are included as a separate component of stockholders' equity, net of
any related tax effect.
55
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Revenue Recognition
The Company's Utility Operations record electric and gas operating
revenues in the period of delivery, which includes estimated amounts for service
rendered but unbilled at the end of each accounting period. Utility Operations'
gas operating revenues exclude adjustments for differences in gas purchase costs
that are above or below levels included in base rates but are recoverable under
the PGAC administered by the PRC. The Company recognizes this adjustment when
PNM is permitted to bill under PRC guidelines.
However, the determination of the energy sales to individual customers is
based on the reading of their meters, which occurs on a systematic basis
throughout the month. At the end of each month, amounts of energy delivered to
customers since the date of the last meter reading are estimated and the
corresponding unbilled revenue is estimated. The cycle meter reading results in
unbilled consumption between the date of the last meter reading in a particular
month and the end of the month. Unbilled electric revenue is estimated each
month based on the daily generation volumes, estimated customer usage by class,
weather factors, line losses and applicable customer rates based on regression
analyses reflecting significant historical trends and experience.
The Company purchases gas on behalf of sales-service customers while
other marketers or producers purchase gas on behalf of transportation service
customers. The Company collects a cost of service revenue for the
transportation, delivery, and customer service provided to these customers.
Sales-service tariffs are subject to the terms of the PGAC while transportation
service customers are metered and billed on the last day of the month.
Therefore, the Company estimates unbilled decatherms and cost of service
revenues for sales-service customers only.
The unbilled decatherms are based on consumption estimates and the
associated cost of service revenue for the period. A cycle bill contains an
amount for both the current period's consumption and the prior period's
consumption. The unbilled portion that is recorded is estimated as a percentage
of the next month's budgeted cycle billings. These budgets are prepared using
historical data adjusted for known trends, including prior period consumption.
Adjustments are also made to the budgeted cycle billings for weather variations
above or below normal, customer growth, and any pricing changes by customer rate
and revenue class. Any differences between the estimate and the actual cycle
billings are recorded in the month billed.
The Company's Wholesale Operations record operating revenues to third
parties in the period of delivery or as services are provided. These electricity
sales are recorded as operating revenues while the electricity purchases are
recorded as costs of energy sold. These amounts are recorded on a gross basis,
because the Company does not act as an agent or broker for these merchant energy
contracts but takes title and has the risks and rewards of ownership. Certain
sales to firm-requirements wholesale customers include a cost of energy
adjustment for recoverable fixed costs. The Company recognizes this adjustment
when it is permitted to bill under FERC guidelines. Wholesale Operations
transactions that are net settled, are recorded gross in operating revenues and
fuel and purchased power expense.
56
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The Company enters into merchant energy contracts to take advantage of
market opportunities associated with the purchase and sale of electricity.
Unrealized gains and losses resulting from the impact of price movements on the
Company's derivative energy contracts that are not deemed normal purchases and
sales or hedges are recognized as adjustments to Wholesale Operations operating
revenues. The market prices used to value these transactions reflect
management's best estimate considering various factors including closing
exchange and over-the-counter quotations, time value and volatility factors
underlying the commitments.
The cash flow impact of these financial instruments is reflected as cash
flows from operating activities in the Consolidated Statement of Cash Flows.
However, in accordance with the Western Systems Power Pool contract,
these revenues are billed in the month subsequent to their delivery.
Consequently, wholesale power marketing revenues for the last month in any
reporting period are unbilled when reported.
Unbilled utility revenues and unbilled wholesale power marketing revenues
are combined and specifically identified in the consolidated balance sheets.
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. The costs are deferred until the period in which they are billed or
credited to customers. The Company's gas purchase costs are recoverable under a
similar Purchased Gas Adjustment Clause administered by the PRC.
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:
2002 2001 2000
----------- ---------- ----------
Electric plant.............. 3.42% 3.39% 3.42%
Gas plant................... 3.02% 3.21% 3.28%
Common plant................ 7.34% 6.92% 6.75%
The provision for depreciation of certain equipment is 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.
57
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
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.
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
early 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.
Financial Instruments
In December 1998, the EITF reached consensus on EITF Issue No. 98-10
which requires that energy trading contracts 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. (See Note 16 for further discussion).
The Company implemented SFAS No. 133, "Accounting for Derivative
Instruments and Hedging Activities," ("SFAS 133"), as amended, on January 1,
2001. SFAS 133, as amended, establishes accounting and reporting standards
requiring derivative instruments to be recorded in the balance sheet as either
an asset or liability measured at their fair value. SFAS 133, as amended, also
requires that changes in the derivatives' fair value be recognized currently in
earnings unless specific hedge accounting or normal purchase and sale 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. SFAS 133, as
amended, provides that the effective portion of the gain or loss on a derivative
instrument designated and qualifying as a cash flow hedging instrument be
reported as a component of other comprehensive income and be reclassified into
earnings in the same period or periods during which the hedged forecasted
transaction affects earnings. The results of hedge ineffectiveness and the
change in fair value of a derivative that an entity has chosen to exclude from
hedge effectiveness are required to be presented in current earnings. All energy
contracts marked-to-market under EITF 98-10 were subject to mark-to-market
accounting upon adoption of SFAS 133 (see further discussion in Note 16).
58
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Stock Options
The Company accounts for stock-based compensation using the intrinsic
value method prescribed in Accounting Principles Board Opinion No. 25,
"Accounting for Stock Issued to Employees." Compensation cost for stock options,
if any, is measured as the excess of the quoted market price of the Company's
stock at the date of grant over the exercise price of the granted stock option.
Restricted stock is recorded as compensation cost over the requisite vesting
periods based on the market value on the date of grant.
SFAS No. 123, "Accounting for Stock-Based Compensation" ("SFAS 123"),
established accounting and disclosure requirements using a fair-value-based
method of accounting for stock-based employee compensation plans. The Company
has elected to remain on its current method of accounting as described above,
and has adopted the disclosure requirements of SFAS No. 123 only (see further
discussion in Note 16).
At December 31, 2002 the Company had three stock-based employee
compensation plans of which options continue to be granted under only two of the
plans. These plans are described more fully in Note 10. Had compensation expense
for the Company's stock options been recognized based on the fair value on the
grant date under the methodology prescribed by SFAS No. 123, 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):
Year Ended December 31,
------------------------------------------
2002 2001 2000
------------- ------------ -------------
Net earnings: (available for common).......... $63,686 $149,847 $100,360
Deduct: Total stock-based employee
compensation expense determined under
fair value based method for all awards,
net of related tax effects................. (4,422) (3,351) (3,578)
------------- ------------ -------------
Pro forma net earnings........................ $59,264 $146,496 $ 96,782
============= ============ =============
Earnings per share:
Basic - as reported....................... $ 1.63 $ 3.83 $ 2.54
============= ============ =============
Basic - pro forma......................... $ 1.51 $ 3.74 $ 2.45
============= ============ =============
Diluted - as reported..................... $ 1.61 $ 3.77 $ 2.53
============= ============ =============
Diluted - pro forma....................... $ 1.50 $ 3.69 $ 2.44
============= ============ =============
59
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Income Taxes
The Company accounts for income taxes in accordance with the provisions
of SFAS No. 109, "Accounting for Income Taxes" ("SFAS No. 109"), which uses the
asset and liability method for accounting for income taxes. Under SFAS 109,
deferred tax assets and liabilities are recognized for the estimated future tax
consequences attributable to differences between the financial statement
carrying value of existing assets and liabilities and their respective tax
basis. Current PRC approved rates include the tax effects of the majority of
these differences. SFAS No. 109 requires that rate-regulated enterprises record
deferred income taxes for temporary differences accorded flow-through treatment
at the direction of a regulatory commission. The resulting deferred tax assets
and liabilities are recorded at the expected cash flow to be reflected in future
rates. Since the PRC has consistently permitted the recovery of previously
flowed-through tax effects, the Company has established regulatory liabilities
and assets offsetting such deferred tax assets and liabilities. 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.
Asset Impairment
The Company evaluates the carrying value of regulatory and tangible
long-lived assets in relation to their future undiscounted cash flows to assess
recoverability in accordance with SFAS 144. Impairment testing of power
generation assets is performed periodically 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.
Change in Presentation
Certain prior year amounts have been reclassified to conform to the 2002
financial statement presentation.
(2) Segment Information
During 2002, the Company's Utility Operations business segment evolved.
With the passage of the Global Electric Agreement, Electric Services
("Electric") became a fully integrated retail energy supply business. As a
result of that evolution, the Company's generation activities changed from a
stand-alone operation to a function that became mostly integrated with the
distribution energy supply business, which primarily serves to optimize the
value of that business. As specified in the Global Electric Agreement, the
Company's generation activities were designated to support either its
rate-regulated electric retail customers or its wholesale customers.
60
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The Holding Company is an investor-owned holding company of energy and
energy related businesses. Its principal subsidiary, PNM, is an integrated
public utility primarily engaged in the generation, transmission, distribution
and sale and marketing of electricity; transmission, distribution and sale of
natural gas within the State of New Mexico and the sale and marketing of
electricity in the Western United States. In addition, the Holding Company
provides energy and technology related services through its wholly-owned
subsidiary, Avistar Inc. ("Avistar").
As it currently operates, the Company's principal business segments are
Utility Operations, Wholesale Operations ("Wholesale") and Corporate and Other.
Utility Operations include Electric Services ("Electric") and Gas Services
("Gas"). These segments model the resource allocations as mandated in the Global
Electric Agreement (see Note 12 - Global Electric Agreement). Certain prior
period amounts have been reclassified to conform to the current year
presentation.
UTILITY OPERATIONS
Electric
Electric consists of the distribution, transmission and generation of
electricity for retail electric customers in New Mexico. 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.
Customer rates for retail electric service are set by the PRC based on the
provisions of the Global Electric Agreement. The Company owns or leases
transmission lines, interconnected with other utilities in New Mexico and south
and east into Texas, west into Arizona, and north into Colorado and Utah.
Gas
The Company's Gas Services distribute natural gas to most of the major
communities in New Mexico, including New Mexico's two largest metropolitan
areas, Albuquerque and Santa Fe. The Company's customer base includes both
sales-service customers and transportation-service customers. PNM purchases
natural gas in the open market and resells it at cost to its distribution
customers. As a result, increases or decreases in gas revenues driven by
wholesale gas prices do not impact the Company's consolidated gross margin or
earnings.
WHOLESALE OPERATIONS
The Company's Wholesale Operations consists of the generation and sale of
electricity into the wholesale market based on three product lines, which are
long-term contracts, forward sales and short-term sales. Long-term contracts
include sales to firm-requirements wholesale customers with multi-year
arrangements. These contracts range from 2 to 17 years with an average of 7.5
years. Forward sales include sales of excess generation and third party
61
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
purchases in the forward market that range from 1 month to 3 years. These
transactions do not qualify as normal sales and purchases as defined in SFAS 133
and as a result, are generally marked to market. Short-term sales generally
include spot market, hour ahead, day ahead and week ahead contracts with terms
of 30 days or less. Also included are sales of any excess generation not
required to fulfill PNM's retail load and contractual commitments. Short-term
sales also cover the revenue credit to retail customers as specified in the
Global Electric Agreement.
CORPORATE AND OTHER
The Holding Company incurs substantially all of the corporate activities
of PNM. These activities are billed to PNM on a cost basis to the extent they
are for the corporate management of PNM and are allocated to the operating
segments. The Holding Company's wholly-owned subsidiary, Avistar, was formed in
August 1999 as a New Mexico corporation and is currently engaged in certain
unregulated and non-utility businesses. In January 2002, Avistar was transferred
by way of a dividend to the Holding Company pursuant to an order from the PRC.
RISKS AND UNCERTAINTIES
The Company's future results may be affected by changes in regional
economic conditions; the outcome of labor negotiations with union employees;
fluctuations in fuel, purchased power and gas prices; the actions of utility
regulatory commissions; changes in law and environmental regulations; the
performance of PNM's generating units and the success of any generation
expansion and external factors such as the weather, including the drought
conditions currently prevalent in New Mexico. In the early 1990s, federal and
state policymakers began investigating and implementing major reforms regarding
the public utility industry, designed to transform electric generation into a
competitive business separate from the regulated monopoly businesses of
transmission and distribution, at least on a functional basis. These reforms
introduced new risks into the Company's business which had the potential to
impact future results, such as the Company's ability to recover stranded costs,
incurred previously in providing power generation to electric service customers,
the market price of electricity and natural gas costs, 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. However, as a result of the energy crisis in California and the
Global Electric Agreement (see Note 12), plans for restructuring the industry
are undergoing fundamental review. Legislation to repeal existing law providing
for customer choice and competition in retail electric power supplies, currently
scheduled to commence in 2007, is being considered in the 2003 session of the
New Mexico Legislature. This legislation, SB 718, has passed the Senate on a
37-2 vote and is currently awaiting action in the House of Representatives. Any
reforms that may be made to existing plans for restructuring the industry will
also affect the Company's future results. In addition to the fate of retail
electric competition in New Mexico, the Company's future results will continue
to be affected on the wholesale side by the market price of electricity and
natural gas costs, and the results of federal reforms regarding the wholesale
market and transmission service.
62
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Summarized financial information by business segment for the years ended
December 31, 2002, 2001 and 2000 is shown below. These amounts include certain
estimates and allocations where necessary.
Utility
--------------------------------------
Corporate
Electric Gas Total Wholesale and Other Consolidated
------------ ------------ ------------ ------------- ------------ ----------------
(In thousands)
2002:
Operating revenues..................... $570,089 $ 272,118 $ 842,207 $251,398 $ 1,404 $ 1,095,009
Depreciation and amortization.......... 71,210 20,718 91,928 6,055 4,426 102,409
Interest income........................ 30,819 436 31,255 4,946 8,753 44,954
Interest charges....................... 33,497 13,547 47,044 14,748 (380) 61,412
Income tax expense (benefit)
from operations...................... 38,176 4,080 42,256 (2,516) (6,709) 33,031
Operating income (loss)................ 78,670 18,167 96,837 8,420 (3,483) 101,774
Segment net income (loss).............. 58,251 6,225 64,476 (3,839) 3,635 64,272
Total assets........................... 1,510,844 505,692 2,016,536 375,237 635,134 3,026,907
Gross property additions............... 149,955 46,676 196,631 23,190 20,404 240,225
Utility
--------------------------------------
Corporate
Electric Gas Total Wholesale and Other Consolidated
------------ ------------ ------------ ------------- ------------ ----------------
(In thousands)
2001:
Operating revenues..................... $559,226 $ 385,418 $ 944,644 $ 1,304,284 $ 1,538 $ 2,250,466
Depreciation and amortization.......... 66,680 20,362 87,042 5,774 4,120 96,936
Interest income........................ 33,775 596 34,371 5,234 9,137 48,742
Interest charges....................... 36,410 11,807 48,217 17,063 (440) 64,840
Income tax expense (benefit)
from operations...................... 25,037 1,605 26,642 78,690 (24,269) 81,063
Operating income....................... 65,752 14,657 80,409 136,237 6,031 222,677
Segment net income (loss).............. 38,202 2,451 40,653 120,071 (10,291) 150,433
Total assets........................... 1,815,250 469,410 2,284,660 365,615 263,513 2,913,788
Gross property additions............... 177,290 48,978 226,268 23,631 14,945 264,844
63
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Utility
--------------------------------------
Corporate
Electric Gas Total Wholesale and Other Consolidated
------------ ------------ ------------ ------------- ------------ ----------------
(In thousands)
2000:
Operating revenues..................... $538,683 $ 319,924 $ 858,607 $650,699 $ 2,233 $ 1,511,539
Depreciation and amortization.......... 62,457 16,132 78,589 5,491 8,979 93,059
Interest income........................ 33,340 9 33,349 5,239 10,107 48,695
Interest charges....................... 37,197 11,088 48,285 17,609 (452) 65,442
Income tax expense (benefit)
from operations...................... 51,259 5,851 57,110 18,709 (1,473) 74,346
Operating income (loss)................ 90,198 16,828 107,026 41,283 (15,835) 132,474
Segment net income (loss).............. 78,216 8,929 87,145 28,549 (14,748) 100,946
Total assets........................... 1,821,666 516,430 2,338,096 278,223 277,914 2,894,233
Gross property additions............... 92,604 40,418 133,022 12,236 1,620 146,878
(Intentionally left blank)
64
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
(3) 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:
2002 2001
------------- --------------
(In thousands)
Assets:
Current:
PGAC............................................... $23,907 $ 9,065
Gas Take-or-Pay Costs.............................. 120 1,408
------------- --------------
Subtotal........................................ 24,027 10,473
------------- --------------
Deferred:
Deferred Income Taxes.............................. 33,321 33,632
Loss on Reacquired Debt............................ 5,978 6,798
Other.............................................. 2,312 710
------------- --------------
Subtotal........................................ 41,611 41,140
Stranded and Transition Assets..................... 154,672 154,227
------------- --------------
(see discussion below)
Total Deferred Assets........................... 196,283 195,367
------------- --------------
Total Assets.................................... 220,310 205,840
------------- --------------
Liabilities:
Deferred:
Deferred Income Taxes.............................. (38,941) (41,915)
Unrealized loss on PVNGS decommissioning trust..... (3,813) (2,137)
Gain on Reacquired Debt............................ (1,495) (1,640)
Other.............................................. (1,755) (2,119)
------------- --------------
Subtotal........................................ (46,004) (47,811)
Stranded and Transition Liabilities................ (20,152) (20,647)
------------- --------------
(see discussion below)
Total Deferred Liabilities...................... (66,156) (68,458)
------------- --------------
Net Regulatory Assets .......................... $ 154,154 $ 137,382
============= ==============
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. The Company does not receive or pay a material rate
of return on these regulatory assets and regulatory liabilities.
65
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The Restructuring Act, as amended, recognizes that electric utilities
should be permitted a reasonable opportunity to recover an appropriate amount of
the costs previously incurred in providing electric service to their customers
("stranded costs"). Stranded costs represent all costs associated with
generation related assets, currently in rates or determined to be recoverable in
rates, in excess of the expected competitive market price of such assets and
include plant decommissioning costs, regulatory assets, and lease and
lease-related costs. Utilities will be allowed to recover no less than 50% of
stranded 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, as amended, also allows for the recovery of nuclear
decommissioning costs by means of a separate wires charge over the life of the
underlying generation assets.
Approximately $135 million of costs associated with the unregulated
businesses under the Restructuring Act, as amended, were established as
regulatory assets. Because of the Company's belief that recovery through rates
is probable as established by law, these assets continue to be classified as
regulatory assets, although the Company's Wholesale Operations has discontinued
SFAS 71 and adopted SFAS 101. On October 10, 2002, the Company and several other
parties signed the Global Electric Agreement which provides for a five year rate
path for the Company's New Mexico retail electric customers beginning in
September 2003 and seeks a repeal of a majority of the Restructuring Act, as
amended. (See Note 12 for further discussion.) As a result, the Company expects
to re-apply SFAS 71 to certain generation activities upon approval by the PRC of
the Global Electric Agreement.
In 2001, the Company recognized the write-off of $13.0 million of
non-recoverable coal mine decommissioning costs previously established as a
regulatory asset. As a result of the Company's evaluation of its regulatory
strategy in light of its holding company filing in May 2001, management
determined that it would not seek recovery of a portion of its previously
established stranded costs that were not a component of retail ratemaking. The
Company may recover the remaining $100 million of costs associated with coal
mine decommissioning that are attributed to New Mexico retail customers in its
Global Electric Agreement which provides for a 17-year recovery of these costs
beginning in September 2003.
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 are presently scheduled
to be recovered beginning 2007 through 2012 by means of a separate wires charge.
Transition costs include professional fees, financing costs including
underwriting fees, costs relating to the transfer of assets, the cost of
management information system changes including billing system changes and
public and customer communications costs. (See Note 12 - Commitments and
Contingencies - Global Electric Agreement for further developments.)
66
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
On December 31, 2001, the Company implemented a holding company structure
without separation of supply service and energy-related service assets from
distribution and transmission service assets as permitted under the amended
Restructuring Act. The Company is unable to predict the form its further
restructuring will take under delayed implementation of customer choice, or if
further restructuring will take place under any repeal of the Restructuring Act.
Regulatory assets and liabilities reflected in the Consolidated Balance
Sheets as of December 31, related to stranded or transition costs are as
follows:
2002 2001
------------ ------------
(In thousands)
Assets:
Transition costs.............................. $ 16,720 $ 15,908
Mine reclamation costs........................ 100,877 100,877
Deferred income taxes......................... 35,708 35,775
Loss on reacquired debt....................... 1,367 1,667
----------- ------------
Subtotal................................. 154,672 154,227
----------- ------------
Liabilities:
Deferred income taxes......................... (14,137) (14,163)
PVNGS prudence audit.......................... (4,682) (5,058)
Settlement due customers...................... (1,325) (1,408)
Gain on reacquired debt....................... (8) (18)
----------- ------------
Subtotal................................. (20,152) (20,647)
----------- ------------
Net Stranded cost and transition cost.... $ 134,520 $ 133,580
=========== ============
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, except for the transition
costs (see further discussion in Note 12).
(4) Capitalization
Common Stock
The number of authorized shares of common stock of the Holding Company is
120 million shares with no par value. The number of shares outstanding was
39,117,799 as of December 31, 2002 and 2001. The only change to common stock of
the Holding Company in 2002 was for the exercise of stock options of $1.8
million. In 2001, the exercise of stock options of $2.2 million was the only
change to additional paid-in-capital of PNM. There were no changes to common
stock or additional-paid-in-capital of PNM in 2002.
67
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The declaration of common dividends is dependent upon a number of factors
including the ability of the Holding Company's subsidiaries to pay dividends.
Currently, PNM is the Holding Company's primary source of dividends. As part of
the order approving the formation of the Holding Company, the PRC placed certain
restrictions on the ability of PNM to pay dividends to its parent.
The PRC order imposed the following conditions regarding dividends paid
by PNM to the holding company: PNM can not pay dividends which cause its debt
rating to go below investment grade; and PNM can not pay dividends in any year,
as determined on a rolling four quarter basis, in excess of net earnings without
prior PRC approval. Additionally, PNM has various financial covenants which
limit the transfer of assets, through dividends or other means.
In addition, the ability of the Company to declare dividends is dependent
upon the extent to which cash flows will support dividends, the availability of
retained earnings, the financial circumstances and performance, the PRC's
decisions in various regulatory cases currently pending and which may be
docketed in the future, the effect of deregulating generation markets and market
economic conditions generally. Conditions imposed by the PRC on holding company
formation, future growth plans and the related capital requirements and standard
business considerations may also affect the Company's ability to pay dividends.
Consistent with the PRC's holding company order, PNM paid dividends of
$127.0 million to the Company on December 31, 2001. On March 4, 2002, the PNM
board of directors declared an additional dividend of approximately $5.5
million, which was paid March 19, 2002. On June 10, 2002, the PNM board of
directors declared a dividend of $24.7 million, which was paid on June 28, 2002.
On February 18, 2003, the Holding Company's board of directors approved a
4.5 percent increase in the common stock dividend. The increase raised the
quarterly dividend to $0.23 per share, for an indicated annual dividend of $0.92
per share.
On August 8, 2000, PNM's board of directors approved a plan to repurchase
up to $35 million of PNM's common stock through the end of the first quarter of
2001. From August 8, 2000 through December 31, 2000, PNM repurchased an
additional 417,900 shares of its outstanding common stock at a cost of $9.0
million.
Cumulative Preferred Stock
No Holding Company preferred stock is outstanding. The Holding Company's
restated articles of incorporation authorize 10 million shares of preferred
stock, which may be issued without restriction. The number of authorized shares
of PNM cumulative preferred stock is 10 million shares. PNM has 128,000 shares,
1965 Series, 4.58%, par 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
68
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
holders of the 1965 Series are entitled to payment before the holders of common
stock in the event of any liquidation or dissolution or distribution of assets
of PNM. In addition, the 1965 Series is not entitled to a sinking fund and
cannot be converted into any other class of stock of PNM.
Long-Term Debt
On March 11, 1998, PNM modified its 1947 Indenture of Mortgage and Deed
of Trust so that no future bonds can be issued under the mortgage. While first
mortgage bonds continue to serve as collateral for Pollution Control Bonds
("PCBs") in the outstanding principal amount of $111 million, the lien of the
mortgage covers only PNM's ownership interest in PVNGS. Senior unsecured notes
("SUNs"), which were issued under a senior unsecured note indenture, serve as
collateral for PCBs in the outstanding principal amount of $463.3 million. With
the exception of the $111 million of PCBs secured by first mortgage bonds, the
SUNs are and will be the senior debt of PNM.
In August 1998, PNM 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. In 1999, PNM retired $31.6 million of its 7.10% SUNs through open
market purchases, utilizing the funds from operations and the funds from
temporary investments leaving an outstanding principal balance of $268.4
million. In January 2000, PNM retired $35.0 million of its 7.5% senior unsecured
notes through open market purchases utilizing funds from operations and the
funds from temporary investments leaving an outstanding principal balance of
$100.0 million. The gains recognized on these purchases were immaterial.
On December 20, 2002, the Holding Company acquired the equity interest of
the grantor trust that owns 60% of the EIP transmission line and related
activities. As a result, $26.1 million of related debt was brought on to the
consolidated balance sheet. This debt was previously disclosed and reported as
off balance sheet debt. The EIP debt bears interest at the rate of 10.25%,
requires semi-annual principal and interest payments and matures on April 1,
2012.
Revolving Credit Facility and Other Credit Facilities
At December 31, 2002, PNM had a $195 million unsecured revolving credit
facility (the "Facility") with an expiration date of December 18, 2003. PNM must
pay commitment fees of 0.2% per year on the unused amount of the Facility. PNM
must also pay a utilization fee of .125% for all borrowings in excess of 33% of
the committed amount. PNM also had $20 million in local lines of credit. In
addition, the Holding Company has a $20 million reciprocal borrowing agreement
with PNM and $15 million in local lines of credit.
There were $150 million in outstanding borrowings bearing interest at a
weighted average interest rate of 2.759% under the Facility as of December 31,
2002. On January 31, 2003, this amount was refunded at an interest rate of
2.325%. PNM was in compliance with all covenants under the Facility.
69
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
(5) Lease Commitments
PNM 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 PNM's PVNGS Units 1 and 2 lease agreements limit
PNM'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.
In 1998, PNM established PVNGS Capital Trust ("Capital Trust") for the
purpose of acquiring all the debt underlying the PVNGS leases. PNM consolidates
Capital Trust in its consolidated financial statements. The purchase was funded
with the proceeds from the issuance of $435 million of SUNS (see Note 4), which
were loaned to Capital Trust. Capital Trust then acquired and holds the debt
component of the PVNGS leases. For legal and regulatory reasons, the PVNGS lease
payment continues to be recorded and paid gross with the debt component of the
payment returned to PNM via Capital Trust. As a result, the net cash outflows
for the PVNGS lease payment were $13.2, $12.4 and $10.7 million in 2002, 2001
and 2000, respectively. The summary of PNM's future minimum operating lease
payments below reflects the net cash outflow related to the PVNGS leases.
PNM's other significant operating lease obligations include a leased
interest in a transmission line with annual lease payments of $7.3 million and a
power purchase agreement for the entire output of a gas-fired generating plant
in Albuquerque, New Mexico, with imputed annual lease payments of $6.0 million.
On December 20, 2002, the Holding Company acquired the equity interest of the
grantor trust, which owns 60% of the EIP transmission line and related
activities.
Future minimum operating lease payments (in thousands) at December 31,
2002 are:
2003.................................... $ 28,216
2004.................................... 28,280
2005.................................... 29,936
2006.................................... 30,753
2007.................................... 31,638
Later years............................. 298,150
---------------
Total minimum lease payments......... $446,973
===============
Operating lease expense, inclusive of the net PVNGS lease payment, was
approximately $34.9 million in 2002, $32.7 million in 2001 and $28.5 million in
2000. Aggregate minimum payments to be received in future periods under
non-cancelable subleases are approximately $4.5 million.
70
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
(6) Fair Value of Financial Instruments
The fair value of a financial instrument is the amount at which the
instrument could be exchanged in a current transaction between willing parties,
other than in a forced sale or liquidation. Although management uses its best
judgment in estimating the fair value of these financial instruments, there are
inherent limitations in any estimation technique. Therefore, the fair value
estimates presented herein are not necessarily indicative of the amounts that
the Company could realize in a current transaction.
Fair value is based on market quotes provided by the Company's investment
bankers and trust advisors. The market prices used to value PNM's mark-to-market
energy portfolio are based on closing exchange prices and over-the-counter
quotations.
The carrying amounts reflected on the consolidated balance sheets
approximate fair value for cash, temporary instruments, receivables, and
payables due to the short period of maturity. The carrying amount and fair value
of the Company's financial instruments (including current maturities) at
December 31 are:
2002 2001
---------------------------------- -------------------------------
Carrying Amount Fair Value Carrying Fair Value
Amount
---------------- ---------------- --------------- ---------------
(In thousands)
Long-Term Debt........................... $ 980,092 $1,027,435 $953,884 $ 973,569
Investment in PVNGS Lessors' Notes....... $ 368,010 $ 436,345 $387,347 $ 417,828
The amortized cost, gross unrealized gain and losses and estimated fair
value of investments in available-for-sale securities at December 31 are as
follows (in thousands):
2002
--------------------------------------------------------------------
Amortized Cost Unrealized Unrealized Fair Value
Gains Losses
---------------- ---------------- --------------- ----------------
(In thousands)
Available-for-sale:
Equity securities................. $ 32,643 $4,134 $ (1,514) $ 35,263
Mortgage-backed securities........ 33,145 410 (93) 33,462
Corporate bonds................... 32,466 438 (19) 32,885
Municipal bonds................... 21,229 1,394 (24) 22,599
U.S. Government securities........ 12,725 702 - 13,427
Other investments................. 14,716 - - 14,716
---------------- ---------------- --------------- ----------------
$ 146,924 $7,078 $(1,650) $ 152,352
================ ================ =============== ================
71
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
2001
--------------------------------------------------------------------
Amortized Cost Unrealized Unrealized Fair Value
Gains Losses
---------------- ---------------- --------------- ----------------
(In thousands)
Available-for-sale:
Mortgage-backed securities........ $ 60,145 $ 92 $ (250) $ 59,987
Equity securities................. 29,965 8,700 (1,595) 37,070
U.S. Government securities........ 36,523 282 (157) 36,648
Corporate bonds................... 32,273 43 (143) 32,173
Municipal bonds................... 21,420 597 (153) 21,864
Other investments................. 31,170 - - 31,170
---------------- ---------------- --------------- ----------------
$ 211,496 $ 9,714 $ (2,298) $218,912
================ ================ =============== ================
At December 31, 2002, the available-for-sale securities held by the
Company had the following maturities (in thousands):
Amortized Cost Fair Value
---------------- ----------------
(In thousands)
Within 1 year............................ $ 6,198 $ 6,203
After 1 year through 5 years............. 41,020 41,838
After 5 years through 10 years........... 4,343 4,511
Over 10 years............................ 48,004 49,821
Equity securities........................ 32,643 35,263
Other investments........................ 14,716 14,716
---------------- ----------------
$ 146,924 $ 152,352
================ ================
The proceeds and gross realized gains and losses on the disposition of
available-for-sale investments are shown in the following table (in thousands).
Realized gains and losses are determined by specific identification.
2002 2001 2000
---------------- ---------------- ---------------
(In thousands)
Proceeds from sales......... $219,880 $80,943 $59,323
Gross realized gains........ 2,537 3,077 8,516
Gross realized losses....... (7,624) (7,476) (5,341)
The Company uses derivative financial instruments to manage risk as it
relates to changes in natural gas and electricity prices, interest rates of
future debt issuances and adverse market changes for investments held by the
Company's various trusts. The Company also uses certain derivative instruments
for wholesale electricity sales in order to take advantage of favorable price
movements and market timing activities in the wholesale power markets.
72
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The Company is exposed to credit risk in the event of non-performance or
non-payment by counterparties of its financial derivative instruments. The
Company uses a credit management process to assess and monitor the financial
conditions of counterparties. The Company's credit risk with its largest
counterparty as of December 31, 2002 and 2001 was $18.7 million and $7.5
million, respectively.
Natural Gas Contracts
Utility Operations
Pursuant to a 1997 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 is recoverable through
the Company's purchased gas adjustment clause as deemed prudently incurred by
the PRC. As a result, earnings are not affected by gains or losses generated by
these instruments.
PNM purchased gas options, a type of hedge, to protect its natural gas
customers from the risk of price fluctuation during the 2002-2003 heating
season. PNM expended $6.0 million to purchase options that limit the maximum
amount the Company would pay for gas during the winter heating season. The
Company recovered its actual hedging expenditures as a component of the PGAC
during the months of October 2002 through February 2003 in equal allotments of
$1.2 million.
Wholesale
Commencing in 2000, the Company's Wholesale Operations conducted a
hedging program to reduce its exposure to fluctuations in prices for natural gas
used as a fuel source for some of its generation. The Wholesale Operations
purchased futures contracts for a portion of its anticipated natural gas needs
in the second, third and fourth quarters of 2001. The futures contracts capped
the Company's natural gas purchase prices at $5.08 to $6.40 per MMBTU and had a
notional amount of $33.6 million. Simultaneously, a delivery location basis swap
was purchased for quantities corresponding to the futures quantities to protect
against price differential changes at the specific delivery points. The Company
accounted for these transactions as cash flow hedges; accordingly, gains and
losses related to these transactions are deferred and recorded as a component of
Other Comprehensive Income. These gains and losses were reclassified and
recognized in earnings as an adjustment to the Company's cost of fuel when the
hedged transaction affected earnings. The fuel hedge program ended in December
2001.
73
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Electricity Contracts
For the year ended December 31, 2002, the Company's wholesale electric
marketing operations settled forward contracts for the sale of electricity that
generated $43.9 million of electric revenues by delivering 1.2 million MWh. The
Company purchased $74.5 million or 1.4 million MWh of electricity to support
these contractual sales and other open market sales opportunities. For the year
ended December 31, 2001, the Company's wholesale electric marketing operations
settled forward contracts for the sale of electricity that generated $77.9
million of electric revenues by delivering 2.1 million MWh. The Company
purchased $76.7 million or 1.9 million MWh of electricity to support these
contractual sales and other open market sales opportunities.
As of December 31, 2002, the Company had open contract positions to buy
$59.7 million and to sell $56.1 million of electricity. At December 31, 2002,
the Company had a gross mark-to-market gain (asset position) on these forward
contracts of $4.8 million and gross mark-to-market loss (liability position) of
$5.7 million, with net mark-to-market loss (liability position) of $0.9 million.
The change in mark-to-market valuation is recognized in earnings each period.
In addition, the Company's Wholesale Operations entered into forward
physical contracts for the sale of the Company's electric capacity in excess of
its retail and wholesale firm requirement needs, including reserves, or the
purchase for retail needs, including reserves, when resource shortfalls exist.
The Company generally accounts for these derivative financial instruments as
normal sales and purchases as defined by SFAS 133, as amended. The Company from
time to time makes forward purchases to serve its retail needs when the cost of
purchased power is less than the incremental cost of its generation. At December
31, 2002, the Company had open forward positions classified as normal sales of
electricity of $141 million and normal purchases of electricity of $99 million.
The Company's Wholesale Operations, including both firm commitments and
other merchant sale activities, are managed through an asset-backed strategy,
whereby the Company's aggregate net open position is covered by its own excess
generation capabilities. The Company is exposed to market risk if its generation
capabilities were disrupted or if its retail load requirements were greater than
anticipated. If the Company were required to cover all or a portion of its net
open contract position, it would have to meet its commitments through market
purchases.
Forward Starting Interest Rate Swaps
PNM currently has $182.0 million of tax-exempt bonds outstanding that are
callable at a premium at December 31, 2002, and an additional $136 million that
become callable at a premium in August 2003. PNM intends to refinance these
bonds, assuming the interest rate of the refinancing does not exceed the current
interest rate of the bonds, and has hedged the entire planned refinancing. The
Company received regulatory approval to refund the tax-exempt bonds on October
29, 2002. This approval is effective for one year. In order to take advantage of
74
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
current low interest rates, PNM entered into five forward starting interest rate
swaps in the fourth quarter of 2001 and the first quarter of 2002. PNM
designated these swaps as cash flow hedges. The hedged risks associated with
these instruments are the changes in cash flows related to general moves in
interest rates expected for the refinancing. The swaps effectively cap the
interest rate on the refinancing to 4.95% plus an adjustment for PNM's and the
industry's credit rating. PNM's assessment of hedge effectiveness is based on
changes in the hedge interest rates. The derivative accounting rules, as
amended, provide that the effective portion of the gain or loss on a derivative
instrument designated and qualifying as a cash flow hedging instrument be
reported as a component of other comprehensive income and be reclassified into
earnings in the same period or periods during which the hedged forecasted
transactions affect earnings. Any hedge ineffectiveness is required to be
presented in current earnings. For the year ended December 31, 2002, PNM
recognized $0.4 million of hedge ineffectiveness in earnings. At December 31,
2002, the fair market value of these derivative financial instruments was
approximately $18.4 million unfavorable to the Company.
A forward starting swap does not require any upfront premium and captures
changes in the corporate credit component of an investment grade company's
interest rate as well as the underlying benchmark. The five forward starting
interest rate swaps have a termination date of May 15, 2003 for a combined
notional amount of $182.0 million. There were no fees on the transaction, as
they are imbedded in the rates, and the transaction will be cash settled on the
mandatory unwind date (strike date), corresponding to the refinancing date of
the underlying debt. The settlement will be capitalized as a cost of issuance
and amortized over the life of the debt as a yield adjustment.
(Intentionally left blank)
75
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
(7) 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:
2002 2001 2000
------------- ------------- -------------
(In thousands, except per share amounts)
Basic:
Net Earnings................................................. $ 64,272 $ 150,433 $ 100,946
Preferred Stock Dividend Requirements........................ 586 586 586
------------- ------------- -------------
Net Earnings Applicable to Common Stock...................... $ 63,686 $ 149,847 $ 100,360
============= ============= =============
Average Number of Common Shares Outstanding.................. 39,118 39,118 39,487
============= ============= =============
Net Earnings per Share of Common Stock (Basic)............... $ 1.63 $ 3.83 $ 2.54
============= ============= =============
Diluted:
Net Earnings................................................. $ 64,272 $ 150,433 $ 100,946
Preferred Stock Dividend Requirements........................ 586 586 586
------------- ------------- -------------
Net Earnings Applicable to Common Stock...................... $ 63,686 $ 149,847 $ 100,360
============= ============= =============
Average Number of Common Shares Outstanding.................. 39,118 39,118 39,487
Diluted Effect of Common Stock Equivalents (a)............... 325 613 223
------------- ------------- -------------
Average Common and Common Equivalent Shares
Outstanding................................................ 39,443 39,731 39,710
============= ============= =============
Net Earnings per Share of Common Stock (Diluted)............. $ 1.61 $ 3.77 $ 2.53
============= ============= =============
(a) Excludes the effect of average anti-dilutive common stock equivalents
related to out of-the-money options of 1,602,277 and 105,336 for the
years ended December 31, 2002 and 2000, respectively. There were no
anti-dilutive common stock equivalents in 2001.
(Intentionally left blank)
76
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
(8) Income Taxes
Income taxes from net earnings consist of the following components:
2002 2001 2000
------------ ------------ ------------
(In thousands)
Current Federal income tax................................ $(9,327) $ 97,661 $ 41,666
Current state income tax.................................. (1,780) 21,220 13,726
Deferred Federal income tax............................... 38,413 (28,967) 19,729
Deferred state income tax................................. 8,856 (5,712) 2,368
Amortization of accumulated investment tax credits........ (3,131) (3,139) (3,143)
------------ ------------ ------------
Total income taxes..................................... $ 33,031 $ 81,063 $ 74,346
Charged to operating expenses............................. $ 20,887 $ 88,769 $ 53,964
Charged to other income and deductions.................... 12,144 (7,706) 20,382
------------ ------------ ------------
Total income taxes..................................... $ 33,031 $ 81,063 $ 74,346
============ ============ ============
The Company's provision for income taxes 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:
2002 2001 2000
------------- ------------ ------------
(In thousands)
Federal income tax at statutory rates.................. $ 34,056 $ 81,024 $ 61,352
Investment tax credits ................................ (3,131) (3,139) (3,143)
Depreciation of flow-through items..................... 2,112 2,249 2,250
Gains on the sale and leaseback of PVNGS
Units 1 and 2....................................... (527) (527) (527)
Equity income from passive investments................. - (1,180) -
Annual reversal of deferred income taxes accrued
at prior tax rates.................................. (1,963) (1,963) (2,477)
Valuation reserve...................................... - (6,552) 6,552
Research and development credit........................ (551) - -
Affordable housing credit.............................. (947) - -
State income tax....................................... 4,715 10,706 8,343
Other ................................................. (733) 445 1,996
------------- ------------ ------------
Total income taxes.................................. $ 33,031 $ 81,063 $ 74,346
============= ============ ============
Effective tax rate 33.95% 35.02% 42.41%
============= ============ ============
77
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The components of the net accumulated deferred income tax liability were:
2002 2001
------------- ------------
(In thousands)
Deferred Tax Assets:
Nuclear decommissioning costs............................... $32,192 $28,138
Regulatory liabilities related to income taxes ............. 37,656 40,594
Minimum pension liability................................... 56,008 19,924
Net operating loss.......................................... - 29,451
Other ...................................................... 57,373 59,049
------------- ------------
Total deferred tax assets ............................... 183,229 177,156
------------- ------------
Deferred Tax Liabilities:
Depreciation ............................................... 216,425 189,157
Investment tax credit ...................................... 41,583 44,714
Fuel costs ................................................. 11,749 5,515
Regulatory assets related to income taxes................... 67,744 68,086
Other ...................................................... 27,043 19,263
------------- ------------
Total deferred tax liabilities .......................... 364,544 326,735
------------- ------------
Valuation allowance......................................... - 29,451
------------- ------------
Accumulated deferred income taxes, net ........................ $181,315 $179,030
============= ============
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........................ $ 2,285
Change in tax effects of income tax related regulatory assets and liabilities...... (2,596)
Tax effect of mark-to-market on investments available for sale..................... 8,365
Tax effect of excess pension liability............................................. 36,084
--------------
Deferred income tax expense for the period...................................... $ 44,138
==============
The Company has no net operating loss carryforwards as of December 31,
2002.
The Company defers investment tax credits related to rate regulated
assets and amortizes them over the estimated useful lives of those assets.
All federal income tax years prior to 1997 are closed, and most issues
for 1997 through 1998 have been resolved. No years are currently under
examination by the IRS.
There are no material differences between the provision for income taxes
and deferred income taxes between the Company and PNM.
78
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
(9) Pension and Other Post-retirement 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 the
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. In addition, in January
2002, the Company made an aggregate contribution of $23.5 million to fund
pension and other post-retirement benefit plans. An additional aggregate
contribution of $1.1 million was made in September 2002 and $1.5 million in
December 2002. The Company contributions to the 401(k) plan consist of a 3%
non-matching contribution, and a 75% match on the first 6% contributed by the
employee on a before-tax basis. The Company contributed $9.5, $9.0 and $8.9
million in the years ended December 31, 2002, 2001 and 2000, respectively.
(Intentionally left blank)
79
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The following sets forth the pension plan's funded status, components of
pension costs and amounts (in thousands) at the plan valuation date of September
30:
Pension Benefits
-----------------------------
2002 2001
-------------- --------------
Change in Projected Benefit Obligation:
Projected benefit obligation at beginning of year.................... $373,434 $321,429
Service cost......................................................... 5,539 5,544
Interest cost........................................................ 27,238 25,758
Amendments........................................................... - 3,560
Actuarial gain....................................................... 41,192 36,143
Benefits paid........................................................ (20,518) (19,000)
-------------- --------------
Projected benefit obligation at end of period.................... 426,885 373,434
-------------- --------------
Change in Plan Assets:
Fair value of plan assets at beginning of year....................... 339,838 389,827
Actual return on plan assets......................................... (20,207) (30,989)
Contribution......................................................... 20,000 -
Benefits paid........................................................ (20,518) (19,000)
-------------- --------------
Fair value of plan assets at end of year......................... 319,113 339,838
-------------- --------------
Funded Status........................................................ (107,772) (33,596)
Unrecognized net actuarial loss...................................... 144,328 48,432
Unrecognized prior service cost...................................... 3,109 3,437
-------------- --------------
Prepaid pension cost............................................. $ 39,665 $ 18,273
============== ==============
The amounts recognized in the Consolidated Balance Sheet consist of:
Accrued benefit liability............................................ $(107,772) $(33,596)
Intangible asset..................................................... 3,109 3,437
Accumulated other comprehensive income............................... 144,328 48,432
-------------- --------------
Net amount recognized............................................. $ 39,665 $ 18,273
============== ==============
Weighted - Average Assumptions as of September 30,
Discount rate........................................................ 6.75% 7.50%
Expected return on plan assets....................................... 9.00% 7.75%
Pension Benefits
-----------------------------------------
2002 2001 2000
------------ ------------ ------------
Components of Net Periodic Benefit Cost:
Service cost................................... $ 5,539 $ 5,544 $ 6,491
Interest cost.................................. 27,238 25,758 23,572
Expected return on plan assets................. (34,497) (29,488) (30,923)
Amortization of net gain....................... - (847) -
Amortization of transition obligation.......... - (1,158) (1,164)
Amortization of prior service cost............. 326 34 34
------------ ------------ ------------
Net periodic pension benefit............... $ (1,394) $ (157) $ (1,990)
============ ============ ============
80
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Other Post-Retirement 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 the plan
valuation date of September 30:
Other Benefits
------------------------------
2002 2001
------------- ---------------
Change in Benefit Obligation:
Benefit obligation at beginning of year.................. $109,408 $ 81,711
Service cost............................................. 2,694 2,644
Interest cost............................................ 8,082 7,906
Amendments............................................... (31,960) -
Unrecognized actuarial loss.............................. 32,876 20,500
Expected benefit paid.................................... (3,304) (3,353)
------------- ---------------
Benefit obligation at end of period.................. 117,796 109,408
------------- ---------------
Change in Plan Assets:
Fair value of plan assets at beginning of year........... 42,132 44,694
Actual return on plan assets.............................. (6,478) (5,161)
Employer contribution.................................... 7,429 6,748
Benefits paid............................................ (2,881) (3,553)
------------- ---------------
Fair value of plan assets at end of year............. 40,202 42,728
------------- ---------------
Funded Status............................................ (77,594) (66,680)
Unrecognized net transition obligation................... 18,171 19,988
Unrecognized net actuarial loss.......................... 74,048 31,763
Unrecognized prior service cost.......................... (31,960) -
------------- ---------------
Accrued post-retirement costs....................... $ (17,335) $ (14,929)
============= ===============
Weighted - Average Assumptions as of September 30,
Discount rate............................................ 6.75% 7.50%
Expected return on plan assets........................... 9.00% 8.25%
Other Benefits
---------------------------------------------
2002 2001 2000
------------- --------------- -------------
Components of Net Periodic Benefit Cost:
Service cost............................................. $ 2,694 $ 2,644 $ 1,053
Interest cost............................................ 8,082 7,906 5,428
Expected return on plan assets........................... (4,505) (3,412) (3,572)
Amortization of net loss................................. 1,320 799 -
Amortization of transition obligation.................... 1,817 1,817 1,817
------------- --------------- -------------
Net periodic post-retirement benefit cost............ $ 9,408 $ 9,754 $ 4,726
============= =============== =============
81
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The effect of a 1% increase in the health care trend rate assumption
would increase the accumulated post-retirement benefit obligation as of
September 30, 2002, by approximately $21.3 million and the aggregate service and
interest cost components of net periodic post-retirement benefit cost for 2002
by approximately $2.0 million. The health care cost trend rate is expected to
decrease to 6.0% by 2011 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 the plan valuation date of September 30, 2002 and 2001, was $19.0
million and $17.7 million, respectively. As of December 31, 2002 and 2001, the
Company has recognized an additional minimum liability of $4.1 million and $2.8
million, respectively, for the amount of unfunded accumulated benefits in excess
of accrued pension costs. The net periodic cost for 2002, 2001 and 2000 was $1.7
million, $1.7 million and $1.9 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 the program.
Marketable securities in the amount of approximately $8.2 million (fair market
value of $8.2 million) are presently in the trust. No additional funds have been
provided to the trust since 1989.
(10) Stock Option Plans
The Company's Performance Stock Plan ("PSP") expired on December 31,
2000. The PSP was a non-qualified stock option plan, covering a group of
management employees. Options to purchase shares of the Company's common stock
were granted at the fair market value of the shares at the close of business on
the date of the grant. Options granted through December 31, 1995 vested on June
30, 1996 and have an exercise term of up to 10 years. All subsequent awards
granted between December 31, 1995 and February 2000, vest three years from the
grant date of the awards. All options vest upon death, disability, retirement,
impaction or involuntary termination other than for cause. Awards granted in
December 2000 vest ratably over three years on the anniversary of the grant
date. The maximum number of options authorized was 5.0 million shares that could
be granted through December 31, 2000. Although the authority to grant options
under the PSP expired on December 31, 2000, the options that were granted
continue to be effective according to their terms.
A new employee stock incentive plan, the Omnibus Performance Equity Plan
("PEP"), became effective with the formation of the Holding Company on December
31, 2001. The PEP provides for the granting of non-qualified stock options,
incentive stock options, restricted stock rights, performance shares,
performance units and stock appreciation rights to officers and key employees.
82
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The total number of shares of common stock subject to all awards under the PEP
may not exceed 2.5 million, subject to adjustment under certain circumstances
defined in the PEP. The number of shares of stock subject to the grant of
restricted stock rights, performance shares and units and stock appreciation
rights is limited to 500,000 shares. Re-pricing of stock options is prohibited
unless specific shareholder approval is obtained. 855,000 options and 1,620
restricted stock rights were awarded in 2002. Under the PEP, 2,500 options were
exercised in 2002. The number of options and restricted stock rights outstanding
as of December 31, 2002 were 847,500 and 1,620, respectively.
Stock options may also be provided to non-employee directors of the
Company under the Company's Director Retainer Plan ("DRP"). Prior to December
31, 2001, non-employee directors could elect to receive payment of the 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 2002 under the DRP
was 35,000 shares with an exercise price of $27.35 and 10,000 with an exercise
price of $20.15 and in 2001 6,000 shares with an exercise price of $22.61. Under
the DRP plan, vesting occurs on the date of the next annual meeting after the
award. Under the DRP 5,000 options were exercised in 2002, 4,000 in 2001 and
4,000 in 2000. The number of options outstanding as of December 31, 2002, was
73,000. Restricted stock issuances were based on the fair market value of the
Company's common stock at the close of business on the date of grant and vest
ratably three years on the anniversary of the grant date. As of December 31,
2002, there was no restricted stock outstanding under the DRP plan. Amendments
to the DRP were approved by the shareholders on July 3, 2001 and the amended
plan became the DRP for the new Holding Company on December 31, 2001. Under the
new DRP, the maximum number of authorized shares was increased from 100,000 to
200,000 (including shares previously granted) through July 1, 2005. The annual
retainer is payable in cash and stock options. Restricted stock is no longer
available under the plan. The exercise price of stock options granted under the
DRP is determined by the fair market value of the stock at the close of business
on the grant date.
(Intentionally left blank)
83
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
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.
2002 2001 2000
-------------------------- -------------------------- ---------------------------
Weighted Weighted Weighted
Average Average Average
Exercise Exercise Exercise
Fixed Options Shares Price Shares Price Shares Price
---------------------------------------- ------------ ------------ ----------- ------------- ------------- ------------
Outstanding at beginning of year..... 2,981,301 $19.100 3,336,221 $19.120 1,574,418 $18.207
Granted.............................. 901,620 $25.745 6,000 $22.610 2,078,500 $19.403
Exercised............................ 356,132 $18.044 299,951 $19.610 296,027 $16.363
Forfeited............................ 16,167 $21.390 60,969 $17.961 20,670 $17.320
------------- ------------- -------------
Outstanding at end of year........... 3,510,622 2,981,301 3,336,221
============= ============= =============
Options exercisable at year-end...... 1,525,345 981,197 916,263
============= ============= =============
Options available for future grant... 1,777,880 2,500,000 -
============= ============= =============
The following table summarizes information about stock options
outstanding at December 31, 2002:
Options Outstanding Options Exercisable
------------------------------------------------------------ --------------------------------
Weighted-
Average Weighted Weighted
Range of Number Remaining Average Number Average
Exercise Outstanding Contractual Exercise Exercisable Exercise
Prices At 12/31/02 Life Prices At 12/31/02 Prices
---------------------------- ---------------- -------------------- ------------------ --------------- ---------------
DRP $5.50 - $27.35 73,000 8.363 years $20.429 28,000 $11.876
PSP $11.50 - $24.313 2,588,502 6.888 years $19.332 1,433,895 $20.644
PEP $ 0 - $28.22 849,120 9.246 years $25.745 63,450 $25.943
---------------- ---------------
3,510,622 7.489 years $20.906 1,525,345 $20.703
================ ===============
84
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The following table summarizes weighted-average fair value of options
granted during the year:
2002 2001 2000
------------ ------------ ------------
PEP......................................... $7.42 $ - $ 7.24
============ ============ ============
DRP......................................... $7.03 $13.94 $ 6.98
============ ============ ============
Total fair market value of all options
granted (in thousands).................... $6,677 $ 83 $15,054
============ ============ ============
The fair value of each option grant is determined on the date of grant
using the Black-Scholes option-pricing model with the following weighted-average
assumptions:
2002 2001 2000
------------- ------------- -------------
Dividend yield.................. 3.43% 3.10% 2.98%
Expected volatility............. 33.62% 33.99% 26.43%
Risk-free interest rates........ 4.87% 5.38% 5.11%
Expected life................... 10.0 years 10.0 years 10.0 years
(11) Construction Program and Jointly-Owned Plants
The Company's construction expenditures for 2002 were approximately $240
million, including expenditures on jointly-owned projects. The Company's
proportionate share of operating and maintenance expenses for the jointly-owned
plants is included in operating expenses in the consolidated statements of
earnings.
At December 31, 2002, 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)...... $710,027 $393,892 $ 9,046 46.3%
Palo Verde Nuclear Generating
Station (Nuclear)*.................... $216,940 $ 67,732 $31,300 10.2%
Four Corners Power Plant Units 4
and 5 (Coal) ........................ $118,509 $ 88,549 $ 6,113 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.
85
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
San Juan Generating Station ("SJGS")
The Company operates and jointly owns SJGS. At December 31, 2002, 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 ("PVNGS")
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 12 for additional discussion.)
(12) Commitments and Contingencies
Long-Term Power Contracts
PNM 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. PNM may reduce its purchases from SPS by 25 MW annually
upon three years' notice. PNM provided such notice to reduce the purchase by 25
MW in 1999 and by an additional 25 MW in 2000. PNM also is party to a master
power purchase and sale agreement with SPS, dated August 2, 1999, pursuant to
which PNM has agreed to purchase 72 MW of firm power from SPS from 2002 through
2005. PNM has 70 MW of contingent capacity obtained from El Paso under a
transmission capacity for generation capacity trade arrangement through
September 2004. Beginning October 2004 and continuing through June 2005, the
capacity amount is 39 MW. PNM holds a power purchased agreement ("PPA") with
Tri-State for 50 MW through June 30, 2010. In addition, PNM is interconnected
with various utilities for economy interchanges and mutual assistance in
emergencies.
In 1996, PNM entered into an operating lease for the rights to all the
output of a new gas-fired generating plant for 20 years. The operating lease's
maximum dependable capacity is 132 MW. In July 2000, the plant went into
operation. The gas turbine generating unit is operated by Delta-Person Limited
Partnership ("Delta") and is located on PNM 's retired Person Generating Station
site in Albuquerque, New Mexico. Primary fuel for the gas turbine generating
unit is natural gas, which is provided by PNM. In addition, the unit has the
capability to utilize low sulfur fuel oil in the event natural gas is not
available or cost effective.
86
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
In July 2001, PNM entered into a long-term wholesale power contract with
Texas-New Mexico Power ("TNMP") to provide power to serve TNMP's firm retail
customers. The contract has a term of 5 1/2 years commencing July 1, 2001. PNM
will provide varying amounts of firm power on demand to complement existing TNMP
contracts. As those contracts expire, PNM will replace them and become TNMP's
sole supplier beginning January 1, 2003. In the last year of the contract, it is
estimated that TNMP will need 114 MW of firm power.
On October 21, 2002, PNM entered into an agreement with FPL Energy LLC
("FPL"), a subsidiary of FPL Group, Inc., to develop a 200 MW wind generation
facility in New Mexico. FPL Energy will build, own and operate the New Mexico
Wind Energy Center ("NMWE"), consisting of 136 wind-powered turbines on a site
in eastern New Mexico. PNM will buy all the power generated by the NMWE under a
25-year contract. Construction of the wind energy site began in January 2003.
Construction on a facility of this size typically takes six to nine months to
complete. PNM will ask the PRC to approve a voluntary tariff that will allow PNM
retail customers to buy wind-generated electricity for a small monthly premium.
Power from the facility not subscribed by PNM retail customers under the
voluntary program will be sold on the wholesale market, either within New Mexico
or outside the state.
In December 2002, PNM entered into a two-year contract to supply 80 MW of
power to U.S. Navy facilities in San Diego, California. PNM began delivering
power under the contract January 1, 2003. The contract runs through March 2005.
Coal Supply
The coal requirements for the SJGS are being supplied by San Juan Coal
Company ("SJCC"), a wholly-owned subsidiary of BHP Holdings, who holds 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
Minerals International, Inc. has guaranteed the obligations of SJCC under the
agreement, which contemplates the delivery of approximately 103 million tons of
coal during its remaining term. That amount would supply substantially all the
requirements of the SJGS through approximately 2017.
Four Corners Power Plant ("Four Corners") is supplied with coal under a
fuel agreement between the owners and BHP Navajo Coal Company ("BNCC"), under
which BNCC agreed to supply all the coal requirements for the life of the plant.
The current fuel agreement expires December 31, 2004. Negotiations for an
extension have been initiated. BNCC 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.
87
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Natural Gas Supply
The Company contracts for the purchase of gas to serve its retail
customers. These contracts are short-term in nature supplying the gas needs for
the current heating season and the following off-season months. The price of gas
is a pass-through, whereby the Company recovers 100% of its cost of gas.
The natural gas used as fuel by Electric and Wholesale was delivered by
Gas. In the second quarter of 2001, Electric and Wholesale began procuring its
gas supply independent of the Company and contracting with the Utility
Operations for transportation services only.
Construction Commitment
PNM had previously committed to purchase five combustion turbines for a
total cost of $151.3 million. The turbines are for planned power generation
plants with an estimated cost of construction of approximately $370 million over
the next five years depending on market conditions. PNM has expended $226
million as of December 31, 2002 of which $144 million was for equipment
purchases. On June 27, 2002, Lordsburg, an 80 MW natural gas fired plant became
fully operational and commenced serving the wholesale power market. Afton, a 141
MW simple cycle gas-fired plant, became fully operational on December 4, 2002.
These plants are part of the Company's ongoing competitive strategy of
increasing generation capacity over time to serve increasing retail load, sales
under long-term contracts and other sales. These plants were not built to serve
New Mexico retail customers and therefore are not currently, included in the
rate base. However, it is possible that these plants may be needed in the future
to serve the growing retail load. If so, these plants will have to be certified
by the PRC and would then be included in the rate base.
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 assessed on an on-going basis. Two replacement steam
generators will be installed in Unit 2 during its Fall 2003 refueling outage.
The Company's share of the fabrication and installation costs (exclusive of
replacement power costs) will be approximately $22 million.
The PVNGS participants ("Participants") have approved the purchase of
replacement steam generators for Units 1 and 3. Preliminary work for the
installation of the replacement steam generators has also been approved by the
Participants. These actions will provide the Participants with options regarding
the replacement of steam generators in Unit 1 and Unit 3. Unit 1 could be
replaced as early as Fall 2005, should the Participants choose to do so. The
Company estimates that its portion of the fabrication and installation costs and
associated power upgrade modifications for Units 1 and 3, will be approximately
$46 million over the period 2002-2003 (exclusive of replacement power costs),
should installation of the ordered replacement steam generators be approved.
88
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Terrorism Insurance
President Bush signed the Terrorism Risk Insurance Act of 2002 (TRIA) on
November 26, 2002. Effective that date, to the extent covered by the act,
endorsements excluding terrorism became null and void. Under the act, insurers
are required to provide a premium quotation to the insured for terrorism
coverage, with limits and deductibles similar to other coverage provided. The
insured must accept and pay the premium, or reject the coverage within 30 days
of receipt of the premium quotation. The Company has accepted all property and
liability insurance offers of TRIA coverage. The Company also purchases
$5,000,000 of non-TRIA terrorism coverage. Four Corners, in which the Company
has a 13% interest in Units 4 and 5, has elected not to purchase TRIA or
non-TRIA property insurance terrorism coverage.
PVNGS Liability and Insurance Matters
The PVNGS participants have financial protection 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 $300 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 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 $27 million, with an annual payment limitation of approximately $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 Price-Anderson Act, the federal law
referred to above, was up for renewal in August 2002. Price-Anderson has been
extended to December 31, 2003.
The PVNGS participants maintain "all-risk" (including nuclear hazards)
insurance for damage to, and decontamination of, property at PVNGS in the
aggregate amount of $2.75 billion as of October 1, 2002, 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 $5.1 million per year.
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PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
PVNGS Decommissioning Funding
PNM 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 2001 decommissioning cost study indicated that PNM's share of the PVNGS
decommissioning costs, excluding spent fuel disposal, would be approximately
$201 million (2001 dollars).
PNM provided an additional $10.7 million, $6.1 million and $3.9 million
funding for the year ended December 31, 2002, 2001 and 2000 respectively, into
the qualified and non-qualified trust funds. The estimated market value of the
trusts for the year ended December 31, 2002 was approximately $63.2 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 domestic power reactors. Under the Waste Act, the DOE was to
develop facilities necessary for the storage and disposal of spent nuclear fuel
and to have the first facility in operation by 1998. The DOE has announced that
such a repository cannot be completed before 2010.
The operator of PVNGS has capacity in existing fuel storage pools at
PVNGS, which can accommodate all fuel expected to be discharged from normal
operation of PVNGS until September 2003. The operator of PVNGS believes that it
will be able to load dry storage casks and place the casks in the completed dry
storage facility prior to September 2003. PNM currently estimates that it will
incur approximately $41.0 million (in 2001 dollars) over the life of PVNGS for
its share of the fuel costs related to the on-site interim storage of spent
nuclear fuel during the operating life of the plant. PNM accrues these costs as
a component of fuel expense, meaning that the charges are accrued as the fuel is
burned. The Company has accrued $1.0 million in 2002 for interim storage costs.
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 2003.
Natural Gas Explosion
On April 25, 2001, a natural gas explosion occurred in Santa Fe, New
Mexico. The apparent cause of the explosion was a leak from a PNM line near the
location. The explosion destroyed a small building and injured two persons who
were working in the building. PNM's investigation indicates that the leak was an
isolated incident likely caused by a combination of corrosion and increased
pressure. PNM also cooperated with an investigation of the incident by the PRC's
90
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Pipeline Safety Bureau (the "Bureau"), which issued its report on March 18,
2002. The Bureau's report gave PNM notice of probable violations of the New
Mexico Pipeline Safety Act and related regulations. PNM and the Bureau staff
entered a compliance agreement addressing the probable violations and filed it
with the PRC for approval on March 4, 2003. PNM agreed to undertake a list of
twenty-four corrective actions, including internal policy changes, retraining
employees and enhancing gas line monitoring. PNM has also agreed to voluntarily
accelerate spending on pipeline replacement by more than $10.0 million and to
commit an additional $1.8 million to development and implementation of systems
to improve gas line management. The compliance agreement is pending before the
PRC-. Two lawsuits against PNM by the injured persons along with several claims
for property and business interruption damages have been resolved.
Global Electric Agreement
In November 2001, PNM began settlement negotiations with the PRC utility
staff and intervenors in order to resolve its merchant plant filing and other
matters. Discussions included the future framework for restructuring the
electric industry in New Mexico under the Restructuring Act, a future retail
electric rate path and PNM's merchant plant filing.
The year-long negotiations ended on October 10, 2002 with the filing of
the Global Electric Agreement with the PRC. The Global Electric Agreement sets a
rate path through 2007 and will resolve the issues surrounding industry
deregulation in New Mexico and the PNM's merchant power strategy. The Global
Electric Agreement was signed by PNM, the PRC Staff, the New Mexico Attorney
General's Office, the New Mexico Industrial Energy Consumers, the City of
Albuquerque, and the University of New Mexico. The United States Executive
Agencies ("USEA") subsequently agreed to support the Global Electric Agreement
as if they had signed it. The Global Electric Agreement also provides for the
signatories to support passage of legislation concerning merchant plant
activities and repeal of a majority of the Restructuring Act in the New Mexico
Legislature.
Under the Global Electric Agreement, PNM will decrease retail electric
rates 6.5% in two phases over the next three years. The first phase will be a
4.0% decrease, effective September 2003. The second phase will be a further 2.5%
decrease from current rate levels, effective in September 2005. Rates would then
be frozen at that level until the end of 2007. In addition, the risks and
benefits of all wholesale electric sales, inure solely to the Company's
shareholders until December 2007. Since the new rate Global Electric Agreement
does not provide for a fuel cost adjustment, the lower fuel costs sought to be
captured by shifting to underground mining for the coal supplies at SJGS will
flow through to the Company's earnings largely offsetting the reduction in
retail revenues.
PNM will be able to seek a general rate adjustment during the rate freeze
period if complying with any new or changed environmental or tax law or
regulation, or a new broader application of existing environmental or tax laws
or regulations, would compromise its financial integrity. PNM also is permitted
to capitalize all the reasonable costs of mandatory renewable energy resources,
including an after-tax cost of capital of 8.64% to be recorded concurrently with
the deferral of those costs.
91
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
PNM is authorized to recover in the stipulated rates and future retail
rates, its New Mexico jurisdictional share of the decommissioning costs
associated with the San Juan, La Plata and Navajo surface coal mines. PNM is
allowed to recover up to $100 million of the costs, composed of approximately
$69 million in surface coal mine reclamation costs, and approximately $31
million of contract buyout costs without being subject to prudence challenge by
the signatories to the Global Electric Agreement. The costs will be amortized
over 17 years commencing September 1, 2003 and in equal amounts each year
thereafter. PNM cannot seek to recover a return on the unamortized reclamation
costs, but could seek to recover a return on the unamortized contract buyout
costs remaining as of December 31, 2007 in future rate adjustment proceedings.
The stipulated rates also provide for full recovery of nuclear
decommissioning costs accrued in accordance with the estimates in the applicable
decommissioning cost study during the rate freeze period for PNM's interests in
PVNGS Units 1 and 2. The portion of SJGS Unit 4 previously treated as an
excluded resource from PNM's New Mexico retail rates are included as a
generation resource to serve PNM's New Mexico retail and wholesale firm
requirements customers' load. PNM's contracts to purchase power from Tri-State,
Delta Limited Partnership and firm power from SPS would also be included as
generation resources to serve PNM's New Mexico retail and wholesale firm
requirements customers' load until each contract expires under the Global
Electric Agreement.
PRC approval or other authorization from the PRC is not required for
PNM's merchant plant investment as long as PNM meets the following conditions:
(a) PNM does not invest more than $1.25 billion in merchant plant; (b) PNM has
an investment grade credit rating on a stand-alone basis and on a consolidated
basis with the Holding Company; and (c) PNM spends at least $60 million per year
in gas and electric utility, non-merchant plant infrastructure needed to
maintain adequate and reliable service. No prior approval for merchant plant
participation would be required and expedited PRC approval would be available
for financing of merchant plant if certain specified financial conditions are
met. If PNM's credit rating on a stand-alone or consolidated basis with the
Holding Company falls below investment grade, however, approvals are needed for
new merchant plant projects and for continuing to participate in merchant plant
projects of more than a certain dollar value and under certain conditions.
PRC approval is not required for PNM to transfer any part of its
interests in merchant plant or PVNGS Unit 3 from time to time to any other legal
entity, provided that the following conditions are met: (a) PNM's debt to
capital ratio will not exceed 65% after giving effect to the transfer and (b)
PNM's investment grade status on a stand-alone basis and on a consolidated basis
with the Holding Company will not be impaired by the transfer of merchant plant
or PVNGS Unit 3 at the time of transfer.
PNM further agreed in the Global Electric Agreement that it will transfer
all its interests in merchant plant out of PNM by January 1, 2010. PNM will
accelerate the mandatory transfer to a date one year after PNM has completed
expenditures of $1.25 billion on merchant plant. PNM may seek a variance from
the PRC at any time prior to January 1, 2010 to extend or vacate the time or
terms and conditions requiring the transfer but not beyond January 1, 2015.
92
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Under the Global Electric Agreement, if merchant plant or PVNGS Unit 3 is
transferred to a PNM affiliate, PNM's generation resources and the affiliate's
generation resources may be jointly dispatched at the merchant affiliate's sole
discretion until January 1, 2015. Joint dispatch of all utility, PVNGS Unit 3 or
merchant plant resources would be terminable at any time between 2008 and 2015
at PNM's discretion, as long as the utility's dispatch capability is not
impaired in any way.
PNM agreed to forego recovery of the costs incurred in preparing to
transition to a competitive retail market in New Mexico. This will result in a
one-time write-off of approximately $16.7 million, pre-tax, upon approval by the
PRC of the Global Electric Agreement.
In the Global Electric Agreement, PNM, PRC utility staff and intervenors
agreed to actively support the repeal of a majority of the Restructuring Act of
1999. If the repeal does not occur during the 2003 New Mexico Legislative
Session, various modifications to the conditions of the Global Electric
Agreement are triggered depending on how long repeal is delayed. SB 718 in the
2003 session would repeal the Restructuring Act as contemplated in the Global
Electric Agreement. On February 28, 2003, SB 718 passed the Senate by a vote of
37-2. It is currently awaiting action in the House of Representatives.
In summary, the terms of this Global Electric Agreement and the Company's
continuing efforts to control expenses offer significant benefits to both
customers and shareholders in the form of lower rates, a predictable rate path,
and the resolution of important issues affecting implementation of the Company's
strategic plan over the next several years.
The Company is currently unable to predict the impact these proceedings
may have on its plans to expand its generating capacity and its future financial
condition and results of operations.
Other
There are various claims and lawsuits pending against the Company. 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 its 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 the litigation effects 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.
93
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The Company is involved in various legal proceedings in the normal course
of business. The associated legal costs for these legal matters are accrued when
incurred. It is also the Company's policy to accrue for legal costs expected to
be incurred in connection with SFAS 5 legal matters when it is probable that a
SFAS 5 liability has been incurred and the amount of expected legal costs to be
incurred is reasonably estimable. These estimates include costs for external
counsel professional fees.
(13) 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 the past acts may
have been lawful at the time they occurred. Sources of potential environmental
liabilities include the Federal Comprehensive Environmental Response
Compensation and Liability Act of 1980 and other similar statutes.
The Company records its environmental liabilities when site assessments
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 such reasonably
likely range of costs (classified as other long-term liabilities at undiscounted
amounts).
The Company's recorded minimum liability estimated to remediate its
identified sites was $8.5 million and $6.8 million as of December 31, 2002 and
2001, respectively. 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.
For the year ended December 31, 2002, 2001 and 2000, the Company spent
$0.7 million, $1.7 million and $1.6 million, respectively, for remediation. The
majority of the December 31, 2002 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.
94
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
(14) Company Realignment
On August 22, 2002, the Company was realigned due to the changes in the
electric industry and particularly, the negative impact on the Company's
earnings and growth prospects from wholesale market uncertainty. The changes
included consolidation of similar functions. A total of 85 salaried and hourly
employees were notified of their termination as part of the realignment. In
accordance with EITF 94-3, "Liability Recognition for Certain Employee
Termination Benefits and Other Costs to Exit an Activity", the Company incurred
a liability of $8.8 million for severance and other related costs associated
with the involuntary termination of employees, which was charged to operations
in the quarter ended September 30, 2002 and is included in administrative and
general in the consolidated statements of earnings for the year ended December
31, 2002. The Company paid $5.8 million through December 31, 2002.
(15) Other Income and Deductions
The following table details the components of other income and deductions
for PNM Resources, Inc. and subsidiaries:
Year Ended December 31,
-------------------------------------------
2002 2001 2000
------------- ------------ -------------
(In thousands)
Other income:
Interest and dividend income....................... $44,954 $48,742 $48,695
Settlement of lawsuit.............................. - - 13,750
Miscellaneous non-operating income................. 3,406 3,405 3,801
------------- ------------ -------------
$48,360 $52,147 $66,246
============= ============ =============
Other deductions:
Merger costs and related legal costs............... $(2,436) $17,975 $6,700
Write-off of Avistar investments................... - 13,089 4,100
Nonrecoverable coal mine decommissioning costs..... - 12,979 -
Write-off of regulatory assets..................... - 11,100 -
Contribution to PNM Foundation..................... - 5,000 -
Transmission line project write-off................ 4,818 - -
Miscellaneous non-operating deductions............. 9,924 7,114 1,150
------------- ------------ -------------
$12,306 $67,257 $11,950
============= ============ =============
95
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
The following table details the components of other income and deductions
for Public Service Company of New Mexico and subsidiaries:
Year Ended December 31,
-------------------------------------------
2002 2001 2000
------------- ------------ -------------
(In thousands)
Other income:
Interest and dividend income........................ $37,632 $48,742 $48,695
Settlement of lawsuit............................... - - 13,750
Miscellaneous non-operating income.................. 2,814 3,405 3,801
------------- ------------ -------------
$40,446 $52,147 $66,246
============= ============ =============
Other deductions:
Merger costs and related legal costs................ $ - $17,975 $6,700
Write-off of Avistar investments.................... - 13,089 4,100
Nonrecoverable coal mine decommissioning costs...... - 12,979 -
Write-off of regulatory assets...................... - 11,100 -
Contribution to PNM Foundation...................... - 5,000 -
Transmission line project write-off................. 4,818 - -
Miscellaneous non-operating deductions.............. 10,241 7,114 1,150
------------- ------------ -------------
$15,059 $67,257 $11,950
============= ============ =============
(16) New and Proposed Accounting Standards
Statement of Financial Accounting Standards No. 143, "Accounting for
Asset Retirement Obligations" ("SFAS 143"). In June 2001, the Financial
Accounting Standards Board ("FASB") issued SFAS 143. SFAS 143 requires the
recognition and measurement of liabilities associated with the retirement of
tangible long-lived assets that result from the acquisition, construction or
development and or the normal operations of the long-lived assets. Retirement
obligations associated with long-lived assets included within the scope of SFAS
143 are those for which a legal obligation exists under enacted laws, statutes,
written or oral contracts, including obligations arising under the doctrine of
promissory estoppel. Under the standard, the asset retirement obligation ("ARO")
liability is recognized at its fair value as incurred.
The recognition of an ARO results in an increase in the carrying cost of
the long-lived asset, which will be amortized using a systematic and rationale
basis over the remaining life of the related asset as depreciation expense. An
ARO represents a future liability and, as a result, accretion expense will be
accrued on this liability until such time as the obligation is satisfied.
Accretion of the ARO liability due to the passage of time is recorded as an
operating expense. If at the end of the asset's life the recorded liability
differs from the actual settled obligation, the Company may incur a gain or loss
that will be recognized at that time. The net difference between the amounts
determined under SFAS 143 and the Company's previous method of accounting for
such activities net of expected regulatory recovery, will be recognized as a
cumulative effect of a change in accounting principle, net of related income
taxes. The Company is currently calculating the liability associated with its
AROs but does not believe there will be a material effect on continuing
operations for the adoption of this standard.
96
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Statement of Financial Accounting Standards No. 145, "Rescission of FASB
Statements No. 4, 44, and 64, Amendment of FASB Statement No. 13, and Technical
Corrections" ("SFAS 145"). In April 2002, the FASB issued SFAS 145. This
statement updates and clarifies existing accounting pronouncements for the
treatment of gains and losses from extinguishment of debt and eliminates an
inconsistency between required accounting for sale-leaseback transactions and
the required accounting for certain lease modifications that have similar
economic effects as sale-leaseback transactions. In accordance with previous
accounting standards, gains and losses from extinguishment of debt were
classified as extraordinary gains and losses. The current statement permits
gains and losses from extinguishment of debt to be classified as ordinary and
included in income from operations, unless they are unusual in nature or occur
infrequently and therefore included as an extraordinary item.
SFAS 145 is effective for fiscal years beginning after May 15, 2002 for
the provisions related to the rescission of FASB Statements No. 4, 44 and 64,
and for all transactions entered into after May 15, 2002 for the provision
related to the amendments of FASB Statement No. 13. The Company does not believe
there will be a material effect from the adoption of this standard on the
Company's consolidated statements of financial position or results of
operations.
Statement of Financial Accounting Standards No. 146, "Accounting for
Costs Associated with Exit or Disposal Activities" ("SFAS 146"). In July 2002,
the FASB issued SFAS 146. This statement requires that a liability for a cost
associated with an exit or disposal activity be recognized at fair value when
the liability is incurred and is effective for exit or disposal activities that
are initiated after December 31, 2002 and nullifies EITF 94-3, "Liability
Recognition for Certain Employee Termination Benefits and Other Costs to Exit an
Activity (including Certain Costs Incurred in a Restructuring)." It also
substantially nullifies EITF Issue No. 88-10, "Costs Associated with Lease
Modification or Termination." Previously issued financial statements, including
interim financial statements, cannot be restated. The Company does not expect
its adoption of this standard in fiscal year 2003 to have a significant impact
on its financial statements.
Statement of Financial Accounting Standards No. 148, "Accounting for
Stock-Based Compensation - Transition and Disclosure, Amendment of FASB
Statement No. 123 and APB Opinion No. 28" ("SFAS 148"). In December 2002, the
FASB issued SFAS 148 that amended SFAS 123 to provide alternative methods of
transition to SFAS 123's fair value method of accounting for stock-based
employee compensation but does not require fair value accounting as prescribed
in SFAS 123. SFAS 148 is effective for fiscal years ending after December 15,
2002. It also amends the disclosure provisions of SFAS 123 and Accounting
Principles Board Opinion No. 28 to require disclosure in the summary of
significant accounting policies of the effects of an entity's accounting policy
with respect to stock-based employee compensation on reported net income and
earnings per share in annual and interim financial statements. The disclosure
provisions of SFAS 148 are incremental to the existing disclosure requirements
of SFAS 123 and are applicable to all companies with stock-based compensation.
The Company adopted the disclosure requirements of this standard in fiscal year
2002, but continues to account for stock-based compensation under APB 25.
97
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
Financial Accounting Standards Board ("FASB") Interpretation No. 45,
"Guarantor's Accounting and Disclosure Requirements for Guarantees, Including
Indirect Guarantees of Indebtedness of Others, an interpretation of FASB
Statements No. 5, 57, and 107 and rescission of FASB Interpretation No. 34"
("FIN 45 "). In November 2002, the FASB issued FIN 45 which enhances the
disclosures to be made by a guarantor in its financial statements about its
obligations under certain guarantees that it has issued. It also requires a
guarantor to recognize, at the inception of a guarantee, a liability for the
fair value of the obligations it has undertaken in issuing the guarantee. FIN 45
applies to contracts or indemnification agreements that contingently require the
guarantor to make payments to the guaranteed party based on changes in an
underlying obligation that is related to an asset, liability, or an equity
security of the guaranteed party. The disclosure requirements are effective for
financial statements of interim or annual periods ending after December 15,
2002. The initial recognition and initial measurement provisions are applicable
on a prospective basis to guarantees issued or modified after December 31, 2002,
irrespective of the guarantor's fiscal year-end. The guarantor's previous
accounting for guarantees issued prior to the date of initial application should
not be revised or restated. The Company adopted FIN 45, and such adoption did
not have a material impact on the financial statements.
Financial Accounting Standards Board ("FASB") Interpretation No. 46,
"Consolidation of Variable Interest Entities", an interpretation of Accounting
Research Bulletin (ARB) No. 51, "Consolidated Financial Statements" ("FIN 46").
In January 2003, the FASB issued FIN 46 to address the consolidation of variable
interest entities that have one or both of the following characteristics: (1)
the equity investment at risk is not sufficient to permit the entity to finance
its activities without additional subordinated financial support from other
parties, which is provided through other interests that will absorb some or all
of the expected losses of the entity and (2) the equity investors lack one or
more of the following essential characteristics of a controlling financial
interest: (a) the direct or indirect ability to make decisions about the
entity's activities through voting rights or similar rights, (b) the obligation
to absorb the expected losses of the entity if they occur, which makes it
possible for the entity to finance its activities, or (c) the right to receive
the expected residual returns of the entity if they occur, which is the
compensation for the risk of absorbing the expected losses. FASB believes that
if a business enterprise has a controlling financial interest in a variable
interest entity, the assets, liabilities, and results of the activities of the
variable interest entity should be included in consolidated financial statements
with those of the business enterprise. FIN 46 requires existing unconsolidated
variable interest entities to be consolidated by their primary beneficiaries if
the entities do not effectively disperse risks among parties involved. There are
also additional disclosure requirements for an enterprise that holds significant
variable interests in a variable interest entity but is not the primary
beneficiary. FIN 46 applies immediately to variable interest entities created
after January 31, 2003, and to variable interest entities in which an enterprise
obtains an interest after that date and may be applied prospectively with a
cumulative-effect adjustment as of the date on which it is first applied or by
restating previously issued financial statements for one or more years with a
cumulative-effect adjustment as of the beginning of the first year restated.
Currently, the Company does not have interests in any variable interest entity.
98
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)
December 31, 2002, 2001 and 2000
EITF 02-3 "Issues Related to Accounting for Contracts Involved in Energy
Trading and Risk Management Activities", EITF 98-10 "Accounting for Contracts
Involved in Energy Trading and Risk Management Activities" and Statement of
Financial Accounting Standards No. 133 "Accounting for Derivative Instruments
and Hedging Activities" ("SFAS 133"). On October 25, 2002, the EITF reached a
final consensus on EITF 02-3 that rescinds EITF 98-10 and requires that all
energy contracts held for trading purposes be presented on a net margin basis in
the statement of earnings. The rescission of EITF 98-10 requires that energy
contracts which do not meet the definition of a derivative under SFAS 133 no
longer be marked to market and recognized in current earnings. As a result, all
contracts which were marked to market under EITF 98-10 and must now be accounted
for under the accrual method should be written back to cost with any difference
included as a cumulative effect of a change in accounting principle in the
period of adoption. This transition provision was effective January 1, 2003. The
rescission of EITF 98-10 did not have a material impact on the Company's
financial condition or results of operations as all contracts previously marked
to market under the definition provided in EITF 98-10 also met the definition of
a derivative under SFAS 133 and are properly recorded at fair value with gains
and losses recorded in earnings. The Company reviewed its energy contract
portfolio to determine whether its contracts meet the definition of trading
activities under EITF 02-3. As a result, the Company has reclassified those
contracts previously accounted for under EITF 98-10 to a net margin basis for
the fiscal years ended December 31, 2002, 2001 and 2000. The Company will not
report revenues and cost of energy sold on a net margin basis on a prospective
basis as a result of the application of EITF 02-3 as none of the Company's
marketing activities meet the definitions of trading activities as prescribed by
EITF 02-3.
The following table details wholesale electric revenues as reclassified
under EITF 02-3. Energy trading margin is included in Electric Operating
Revenues in the Statement of Earnings:
Year Ended December 31,
2002 2001 2000
------------- -------------- --------------
(In thousands)
Wholesale revenues.............................. $76,226 $60,982 $80,207
Wholesale purchases (EITF 02-3 adjustment)...... (73,987) (89,351) (99,735)
------------- -------------- --------------
Energy trading margin........................... $ 2,239 $ (28,369) $ (19,528)
============= ============== ==============
99
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
QUARTERLY OPERATING RESULTS
The unaudited operating results by quarters for 2002 and 2001 are as
follows:
Quarter Ended
------------------------------------------------------------------
March 31 June 30 September 30 December 31
------------- --------------- ----------------- --------------
(In thousands, except per share amounts)
2002:
Operating Revenues................. $ 297,508 $ 245,625 $ 269,977 $ 281,899
Operating Income................... 32,687 19,449 29,135 20,503
Net Earnings....................... 24,949 11,157 17,797 10,369
Net Earnings per Share (Basic)..... 0.63 0.28 0.45 0.26
Net Earnings per Share (Diluted)... 0.63 0.28 0.45 0.26
2001:
Operating Revenues................. $ 719,767 $ 634,359 $ 588,527 $ 307,813
Operating Income................... 77,300 80,547 47,422 17,408
Net Earnings ...................... 63,552 49,597 32,775 4,509
Net Earnings per Share (Basic)..... 1.62 1.26 0.83 0.11
Net Earnings per Share (Diluted)... 1.60 1.24 0.82 0.11
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.
100
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
COMPARATIVE OPERATING STATISTICS
(Unaudited)
2002 2001 2000 1999 1998
--------------- -------------- -------------- -------------- -------------
Utility Operations Sales:
Energy Sales--KWh (in thousands):
Residential.................................. 2,298,542 2,197,889 2,171,945 2,027,589 2,022,598
Commercial................................... 3,254,576 3,213,208 3,133,996 2,981,656 2,909,752
Industrial................................... 1,612,723 1,603,266 1,544,367 1,559,155 1,571,824
Other ultimate customers..................... 240,665 240,934 238,635 235,183 235,700
--------------- -------------- -------------- -------------- -------------
Total KWh sales............................ 7,406,506 7,255,297 7,088,943 6,803,583 6,739,874
=============== ============== ============== ============== =============
Gas Throughput--Decatherms (in thousands):
Residential.................................. 29,627 27,848 28,810 32,121 29,258
Commercial................................... 12,009 10,421 9,859 11,106 10,044
Industrial................................... 749 3,920 5,038 2,338 1,553
Other........................................ 4,806 4,355 6,426 6,538 8,390
--------------- -------------- -------------- -------------- -------------
Total gas sales............................ 47,191 46,544 50,133 52,103 49,245
Transportation throughput.................... 44,889 51,395 44,871 40,161 36,413
--------------- -------------- -------------- -------------- -------------
Total gas throughput....................... 92,080 97,939 95,004 92,264 85,658
=============== ============== ============== ============== =============
Revenues (in thousands):
Electric Revenues:
Residential.................................. $ 197,174 $ 187,600 $ 186,133 $ 184,088 $ 187,681
Commercial................................... 247,800 242,372 238,243 238,830 241,968
Industrial................................... 82,009 82,752 79,671 85,828 88,644
Other ultimate customers..................... 14,942 14,795 14,618 13,777 18,124
--------------- -------------- -------------- -------------- -------------
Total revenues to ultimate customers....... 541,925 527,519 518,665 522,523 536,417
Transmission revenues........................ 23,150 26,553 16,855 15,519 15,596
Miscellaneous electric revenues.............. 5,014 5,154 3,163 2,826 3,555
--------------- -------------- -------------- -------------- -------------
Total electric revenues.................... $ 570,089 $ 559,226 $ 538,683 $ 540,868 $ 555,568
--------------- -------------- -------------- -------------- -------------
Gas Revenues:
Residential.................................. $ 172,200 $ 232,321 $ 191,231 $ 152,266 $ 160,398
Commercial................................... 52,530 68,895 52,964 37,337 42,480
Industrial................................... 2,872 27,519 24,206 8,550 4,887
Other........................................ 20,906 28,896 29,203 20,080 27,218
--------------- -------------- -------------- -------------- -------------
Revenues from gas sales...................... 248,508 357,631 297,604 218,233 234,983
Transportation............................... 17,735 20,188 14,163 12,390 13,464
Other........................................ 5,875 7,599 8,157 6,088 7,528
--------------- -------------- -------------- -------------- -------------
Total gas revenues......................... $ 272,118 $ 385,418 $ 319,924 $ 236,711 $ 255,975
--------------- -------------- -------------- -------------- -------------
Total Utility Revenues................ $ 842,207 $ 944,644 $ 858,607 $ 777,579 $ 811,543
=============== ============== ============== ============== =============
101
PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO
COMPARATIVE OPERATING STATISTICS
(Unaudited)
2002 2001 2000 1999 1998
--------------- -------------- -------------- -------------- -------------
Utility Customers at Year End:
Electric:
Residential............................. 345,588 340,656 332,332 321,949 319,415
Commercial.............................. 41,092 40,065 39,525 38,435 37,652
Industrial.............................. 311 377 371 375 363
Other ultimate customers................ 796 924 625 625 665
--------------- -------------- -------------- -------------- -------------
Total ultimate customers.............. 387,787 382,022 372,853 361,384 358,095
Sales for Resale........................ 76 79 81 83 83
--------------- -------------- -------------- -------------- -------------
Total customers....................... 387,863 382,101 372,934 361,467 358,178
=============== ============== ============== ============== =============
Gas:
Residential............................. 411,642 404,753 398,623 390,428 383,292
Commercial.............................. 35,194 32,894 32,626 32,116 32,004
Industrial.............................. 58 50 50 51 55
Other................................... 3,664 3,528 3,612 3,688 3,622
Transportation.......................... 27 34 32 32 29
--------------- -------------- -------------- -------------- -------------
Total customers....................... 450,585 441,259 434,943 426,315 419,002
=============== ============== ============== ============== =============
Wholesale Operations Sales:
Energy Sales--KWh (in thousands):
Long-term contracts..................... 844,168 1,463,031 330,003 1,185,916 1,211,176
Other merchant sales.................... 7,269,242 10,596,004 10,213,725 8,585,705 7,571,139
--------------- -------------- -------------- -------------- -------------
Total sales to ultimate customers..... 8,113,410 12,059,035 10,543,728 9,771,621 8,782,315
=============== ============== ============== ============== =============
Revenues (in thousands):
Long-term contracts..................... $ 40,132 $ 77,250 $ 87,731 $ 66,353 $ 66,947
Other merchant sales.................... 192,968 1,224,388 556,146 250,853 208,025
--------------- -------------- -------------- -------------- -------------
Total revenues to ultimate customers.. 233,100 1,301,638 643,877 317,206 274,972
Miscellaneous electric revenues......... 18,298 2,646 6,822 7,703 4,657
--------------- -------------- -------------- -------------- -------------
Total wholesale revenues.............. $ 251,398 $ 1,304,284 $ 650,699 $ 324,909 $ 279,629
=============== ============== ============== ============== =============
Customers at Year End:
Wholesale................................. 76 79 81 83 83
=============== ============== ============== ============== =============
Generation Statistics:
Reliable Net Capability--KW............... 1,734,000 1,521,000 1,521,000 1,521,000 1,506,000
Coincidental Peak Demand--KW.............. 1,456,000 1,397,000 1,368,000 1,291,000 1,313,000
Average Fuel Cost per Million BTU......... $ 1.3910 $ 1.6007 $ 1.3827 $ 1.3169 $ 1.2433
BTU per KWh of Net Generation............. 10,568 10,549 10,547 10,490 10,784
102
INDEPENDENT AUDITORS' REPORT
To the Board of Directors and Stockholders of PNM Resources, Inc. and
Public Service Company of New Mexico
We have audited the consolidated financial statements of PNM Resources, Inc. and
subsidiaries and Public Service Company of New Mexico and subsidiaries
(collectively, the Company) as of December 31, 2002 and 2001, and for each of
the three years in the period ended December 31, 2002, and have issued our
reports thereon dated February 11, 2003. Our audits also included the financial
statement schedules listed in Item 15. These financial statement schedules are
the responsibility of the Company's management. Our responsibility is to express
an opinion based on our audits. In our opinion, such financial statement
schedules, when considered in relation to the basic consolidated financial
statements taken as a whole, present fairly in all material respects the
information set forth therein.
DELOITTE & TOUCHE LLP
Omaha, Nebraska
February 11, 2003
103
SCHEDULE I
The PNM Resources, Inc. holding company structure was effected through a
one-for-one share exchange between the shareholders of Public Service Company of
New Mexico ("PNM") and PNM Resources, Inc. (the "Holding Company") on December
31, 2001, whereby the shareholders of PNM became shareholders of the Holding
Company and the Holding Company acquired all of PNM's common stock. The Holding
Company has no significant operations other than billings of corporate
activities to PNM on a cost basis and its equity interest in PNM. There were no
material Holding Company operations in 2001; therefore, a statement of earnings
is not presented for 2001.
PNM RESOURCES, INC.
CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY
BALANCE SHEET
As of December 31,
2002 2001
------------- --------------
(In thousands)
Assets
Cash and cash equivalents................................... $ - $ 11,380
Intercompany receivables.................................... 48,736 -
Short-term investments...................................... 79,630 -
Other current assets........................................ 10,091 9,951
------------- --------------
Total current assets..................................... 138,457 21,331
------------- --------------
Property, plant and equipment, net of accumulated
depreciation of $5,839.................................... 72,068 -
Long-term investments....................................... - 105,669
Investment in subsidiaries.................................. 864,738 885,328
Other long-term assets...................................... 15,694 -
------------- --------------
Total long-term assets................................... 952,500 990,997
------------- --------------
Total Assets............................................. $1,090,957 $1,012,328
============= ==============
Liabilities and Shareholder's Equity
Current liabilities......................................... $ 23,300 $ -
Long-term debt.............................................. 26,152 -
Other long-term liabilities................................. 1,737 -
------------- --------------
Total Liabilities........................................ 51,189 -
------------- --------------
Common stock, 39,118 shares, issued and authorized.......... 1,010,510 1,012,328
Accumulated other comprehensive income, net of tax.......... (591) -
Retained earnings........................................... 29,849 -
------------- --------------
Total common stockholder's equity........................ 1,039,768 1,012,328
------------- --------------
Total Liabilities and Shareholder's Equity............... $1,090,957 $1,012,328
============= ==============
104
PNM RESOURCES, INC.
CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY
STATEMENTS OF EARNINGS
Year ended
December 31,
2002
------------------
(In thousands)
Operating revenues.............................. $ 72,865
Operating expenses.............................. 79,543
--------------
Operating loss............................... (6,678)
--------------
Other income and deductions:
Equity in earnings of subsidiaries.............. 61,042
Other income.................................... 11,289
Other deductions................................ (450)
--------------
Net other income and deductions.............. 71,881
--------------
Income before income taxes...................... 65,203
Income tax expense.............................. 931
--------------
Net income...................................... $ 64,272
==============
105
SCHEDULE I
PNM RESOURCES, INC.
CONDENSED FINANCIAL INFORMATION OF PARENT COMPANY
STATEMENT OF CASH FLOWS
Year Ended December 31,
2002 2001
--------------------------------
(In thousands)
Cash Flows From Operating Activities:
Net earnings........................................................... $ 64,272 $ -
Adjustments to reconcile net earnings to net cash flows
from operating activities:
Depreciation and amortization...................................... 715 -
Accumulated deferred income tax.................................... (2,542) -
Equity in earnings of subsidiaries................................. (61,042) -
Changes in certain assets and liabilities:
Other assets..................................................... (3,882) -
Accounts payable................................................. 2,579 -
Other liabilities................................................ 22,458 -
--------------- ---------------
Net cash flows provided by operating activities............ 22,558 -
--------------- ---------------
Cash Flows From Investing Activities:
Property plant and equipment........................................... (20,405) -
Redemption of short-term investments................................... 31,012 -
Cash dividends from subsidiaries....................................... 30,206 127,000
Short-term and long-term investments................................... - (115,620)
Other.................................................................. 10,194 -
--------------- ---------------
Net cash flows used for investing activities............... 51,007 11,380
--------------- ---------------
Cash Flows From Financing Activities:
Exercise of employee stock options (note 10)........................... (1,785) -
Dividends paid......................................................... (34,424) -
Change in intercompany accounts........................................ (48,736) -
--------------- ---------------
Net cash flows provided by (used for) financing activities. (84,945) -
--------------- ---------------
Decrease in Cash and Cash Equivalents.................................... (11,380) 11,380
Beginning of Year........................................................ 11,380 -
--------------- ---------------
End of Year.............................................................. $ - $ 11,380
=============== ===============
Supplemental cash flow disclosures:
Income taxes paid, net................................................. $ 3,640 $ -
=============== ===============
Non-cash dividends from subsidiaries................................... $ 34,880 $ -
=============== ===============
Long-term debt assumed for transmission line........................... $ 26,152 $ -
=============== ===============
106
SCHEDULE II
PNM RESOURCES, INC.
PUBLIC SERVICE COMPANY OF NEW MEXICO
VALUATION AND QUALIFYING ACCOUNTS
Additions Deductions
---------------------------------- ---------------
Balance at Charged to Charged to
beginning of costs and other Write off Balance at
Description year expenses accounts adjustments end of year
-------------------------------------------- -------------- ---------------- -------------- --------------- ---------------
(In thousands)
Allowance for doubtful accounts, year ended December 31:
2000 $12,504 $14,296 $ - $13,521 $ 13,279
2001 $13,279 $10,312 $ - $ 5,566 $ 18,025
2002 $18,025 $ (2,450) $ - $ - $ 15,575
Allowance for market and credit volatility year ended December 31:
2000 $ - $ 4,139 $ - $ - $ 4,139
2001 $ 4,139 $ (1,090) (a) $ - $ - $ 3,049
2002 $ 3,049 $ (616) $ - $ - $ 2,433
(a) Represents a change in assessed market and credit volatility risk by
the Company (see "Item 7. Management's Discussion and Analysis of
Results of Operations and Financial Condition - Critical Accounting
Policies").
107
Item 7. Financial Statements, Pro Forma Financial Information and Exhibits
(c) Exhibits
15.1 Letter Re: Unaudited Interim Financial Information for PNM Resources,
Inc. and Subsidiaries.
15.2 Letter Re: Unaudited Interim Financial Information for Public Service
Company of New Mexico.
99.1 Chief Executive Officer Certification Pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002.
99.2 Chief Financial Officer Certification Pursuant to Section 302 of the
Sarbanes-Oxley Act of 2002.
99.3 Chief Executive Officer Certification Pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002.
99.4 Chief Financial Officer Certification Pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002.
108
SIGNATURE
Pursuant to the requirements of the Securities Exchange Act of 1934, the
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
PNM RESOURCES, INC.
---------------------------------------------
(Registrant)
Date: June 12, 2003 /s/ Robin A. Lumney
---------------------------------------------
Robin A. Lumney
Vice President, Controller
and Chief Accounting Officer
(Officer duly authorized to sign this report)
109