UNITED STATES SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549
FORM 10-K

ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934

For the Fiscal Year Ended December 31, 2002

 Commission        Registrant, 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

           Securities Registered Pursuant To Section 12(b) Of The Act:

                                                          Name of Each Exchange
Registrant             Title of Each Class                 on Which Registered
----------             -------------------                 -------------------
PNM Resources, Inc.    Common Stock, No Par Value        New York Stock Exchange

Securities Registered Pursuant To Section 12(g) Of The Act:

Registrant                                   Title of Each Class
----------                                   -------------------
Public Service Company             1965 Series, 4.58% Cumulative Preferred Stock
of New Mexico                      ($100 stated value without sinking fund)

Indicate by check mark whether each registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports) and (2) has been subject to such filing requirements for the past 90 days. YES |X| NO

Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrants' knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. __

Indicate by check mark whether the registrant is an accelerated filer (as defined in Rule 12b-2 of the Act). YES |X| NO

The total number of shares of Common Stock of PNM Resources, Inc. outstanding as of January 31, 2003 was 39,117,799.

On June 28, 2002, the aggregate market value of the voting stock held by non-affiliates of PNM Resources, Inc. as computed by reference to the New York Stock Exchange composite transaction closing price of $24.20 per share reported by The Wall Street Journal, was $946,650,736.


DOCUMENTS INCORPORATED BY REFERENCE

Portions of the following document are incorporated by reference into the indicated part of this report:

Proxy Statement to be filed by PNM Resources, Inc. with the Securities and Exchange Commission pursuant to Regulation 14A relating to the annual meeting of stockholders of PNM Resources, Inc. to be held on May 13, 2003 - PART III.

This combined Form 10-K represents separate filings by PNM Resources, Inc. and Public Service Company of New Mexico ("PNM"). Information combined herein relating to an individual registrant is filed by that registrant on its own behalf. PNM makes no representations as to the information relating to PNM Resources, Inc. and its subsidiaries other than PNM. When this combined Form 10-K is incorporated by reference into any filing with the SEC made by PNM, the portions of this Form 10-K that relate to PNM Resources, Inc. and its subsidiaries other than PNM are not incorporated by reference therein.

ii

                                TABLE OF CONTENTS
                                                                            Page
                                                                            ----
GLOSSARY....................................................................  v

                                                  PART I

ITEM  1. BUSINESS...........................................................  1
              THE COMPANY...................................................  1
              COMPANY WEBSITE...............................................  1
              UTILITY OPERATIONS............................................  2
                  Electric..................................................  2
                  Gas.......................................................  3
              GENERATION AND MARKETING OPERATIONS...........................  4
                 Power Sales................................................  4
                  Sources of Power..........................................  6
                  Fuel and Water Supply.....................................  7
              UNREGULATED OPERATIONS........................................  9
              RATES AND REGULATION.......................................... 10
                  Electric Rates and Regulation............................. 10
                  Gas Rates and Regulation.................................. 13
              ENVIRONMENTAL MATTERS......................................... 14
              COMPETITION................................................... 15
              EMPLOYEES..................................................... 16

ITEM  2. PROPERTIES......................................................... 16
              ELECTRIC...................................................... 16
                  Fossil-Fueled Plants...................................... 17
                  Nuclear Plant............................................. 17
                  Other Electric Properties................................. 19
              NATURAL GAS................................................... 19
              OTHER INFORMATION............................................. 19

ITEM  3. LEGAL PROCEEDINGS.................................................. 19
                 Navajo Nation Environmental Issues......................... 19
                 KAFB Contract.............................................. 20
                 PVNGS Water Supply Litigation.............................. 21
                 San Juan River Adjudication................................ 21
                 Natural Gas Royalties Qui Tam Litigation................... 22
                 Santa Fe Generation Station................................ 22
                 Former AG&E Manufactured Gas Plant Site.................... 23
                 Citizen Suit Under the Clean Air Act....................... 24
                 Landowner Environmental Claims............................. 24
                 California Attorney General Complaint...................... 24
                 California Antitrust Litigation............................ 24

ITEM  4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS................ 25

SUPPLEMENTAL ITEM. EXECUTIVE OFFICERS OF THE COMPANY........................ 25


                                      iii

                                     PART II

                                                                            Page
                                                                            ----
ITEM  5.   MARKET FOR THE COMPANY'S COMMON EQUITY AND
                 RELATED STOCKHOLDER MATTERS...............................  28
ITEM  6.   SELECTED FINANCIAL DATA.........................................  29
ITEM  7.   MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL
                 CONDITION AND RESULTS OF OPERATION........................  30
ITEM  7A. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT
                      MARKET RISK..........................................  81
ITEM  8.    FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.................... F-1
ITEM  9.   CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON
                ACCOUNTING AND FINANCIAL DISCLOSURE........................ E-1

                                                 PART III

ITEM 10.   DIRECTORS AND EXECUTIVE OFFICERS OF THE COMPANY................. E-1
ITEM 11.   EXECUTIVE COMPENSATION.......................................... E-1
ITEM 12.   SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND
                MANAGEMENTAND RELATED STOCKHOLDER MATTERS.................. E-1
ITEM 13.   CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS.................. E-1
ITEM 14.   CONTROLS AND PROCEDURES......................................... E-1

                                                  PART IV

ITEM 15.   EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
                ON FORM 8-K................................................ E-1
SIGNATURES.................................................................E-27
CERTIFICATIONS.............................................................E-28

iv

GLOSSARY

Act...................  The Clean Air Act Amendments of 1990
Afton.................  Afton Generating Station
Avistar...............  Avistar, Inc., an unregulated subsidiary of PNM
                           Resources, Inc.
AG....................  New Mexico Attorney General
AG&E..................  Albuquerque Gas and Electric Company
AMDAX.................  AMDAX.com, an equity investee of Avistar
Anaheim...............  City of Anaheim, California
APPA..................  Arizona Power Pooling Association
APS...................  Arizona Public Service Company
BHP...................  BHP Billiton
BLM...................  Bureau of Land Management
BNCC..................  BHP Navajo Coal Company
BTU...................  British Thermal Unit
COA...................  City of Albuquerque, New Mexico
Decatherm.............  1,000,000 BTUs
Delta.................     Delta-Person Limited Partnership, a
                           New Mexico limited partnership
DOE...................  United States Department of Energy
EIP...................  Eastern Interconnection Project
El Paso...............  El Paso Electric Company
EPA...................  United States Environmental Protection Agency
EPNG..................  El Paso Natural Gas Company
Exchange Act..........  SEC Exchange Act of 1934
FASB..................  Financial Accounting Standards Board
Farmington............  City of Farmington, New Mexico
FERC..................  Federal Energy Regulatory Commission
FIP...................  Federal Implementation Plan
Four Corners..........  Four Corners Power Plant
FPL...................  FPL Energy LLC
FPPCAC................  Fuel and Purchased Power Cost Adjustment Clause
Gallup................  City of Gallup, New Mexico
Gathering Company.....  Sunterra  Gas  Gathering  Company,  a  wholly-owned
                           subsidiary  of  PNM Resources, Inc.
ISO...................  Independent System Operator
Jicarilla.............  Jicarilla Apache Tribe
KAFB..................  Kirtland Air Force Base
Kv....................  Kilovolt
KW....................  Kilowatt
KWh...................  Kilowatt Hour
Lordsburg.............  Lordsburg Generating Station
Los Alamos............  The County of Los Alamos, New Mexico
mcf...................  Thousand cubic feet
Meadows...............      Meadows Resources, Inc., a
                            wholly-owned subsidiary of Public
                            Service Company of New Mexico

                                       v

M-S-R.................  M-S-R Public Power Agency, a California public power
                           agency
MW....................  Megawatt
MWh...................  Megawatt Hour
NMED..................  New Mexico Environment Department
NMPUC.................  New Mexico Public Utility Commission
NMWE..................  New Mexico Wind Energy Center
NOPR..................  Notice of Proposed Rulemaking
NRC...................  United States Nuclear Regulatory Commission
NSPS..................  New Source Performance Standards
NSR...................  New Source Review
OCD...................  New Mexico Oil Conservation Division
OMOI..................  Office of Market Oversight and Investigation
PGAC..................  PNM's Purchased Gas Adjustment Clause
PG&E..................  Pacific Gas and Electric Co.
PLP...................  Cobisa-Person Limited Partnership
PPA...................  Power Purchase Agreement
PRC...................  New Mexico Public Regulation Commission, successor to
                            the NMPUC
Processing Company....  Sunterra  Gas  Processing  Company,  a  wholly-owned
                            subsidiary  of  PNM Resources, Inc.
PSD...................  Prevention of Significant Deterioration
PVNGS.................  Palo Verde Nuclear Generating Station
RCRA..................  Resource Conservation and Recovery Act
RHC...................  Republic Holding Company
RSB...................  Republic Savings Bank
RTO...................  Regional Transmission Organization
Reeves Station........  Reeves Generating Station
Salt River Project....  Salt River Project Agricultural Improvement and Power
                           District
SCE...................  Southern California Edison Company
SCPPA.................  Southern California Public Power Authority
SDG&E.................  San Diego Gas and Electric Company
SEC...................  Securities and Exchange Commission
SJCC..................  San Juan Coal Company
SJGS..................  San Juan Generating Station
SO2...................  Sulfur Dioxide
SPS...................  Southwestern Public Service Company
TNP...................  Texas-New Mexico Power Company
Throughput............  Volumes of gas delivered, whether or not owned by the
                           Company
Tri-State.............  Tri-State Generation and Transmission Association, Inc.
Tucson................  Tucson Electric Power Company
UAMPS.................  Utah Associated Municipal Power Systems
USBR..................  United States Bureau of Reclamation
USEA..................  United States Executive Agencies
USEC..................  United States Enrichment Corporation
WGA...................  Western Governors Association

                                       vi

WRAP..................  Western Regional Air Partnership
Waste Act.............  Nuclear Waste Policy Act of 1982, as amended in 1987
WAPA..................  Western Area Power Administration
Williams..............     Williams Gas Processing-Blanco,
                           Inc., a subsidiary of the Williams
                           Field Services Group, Inc., of
                           Tulsa, Oklahoma

vii

PART I

ITEM 1. BUSINESS

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 the Holding Company. 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.

The Company operates as three distinct business units: (1) Utility Operations, (2) Generation and Marketing Operations and (3) Unregulated Operations. Utility Operations and Generation and Marketing Operations are business units of PNM. Utility Operations include Electric Services ("Electric") and Gas Services ("Gas"). Electric consists of the distribution of electricity, as well as all activities related to the Company's electric transmission operations. Gas includes the transportation and distribution of natural gas to end-users. Generation and Marketing Operations include all production and purchase of electricity, the sale of wholesale electricity to Utility Operations and third parties, as well as electricity marketing activities. Unregulated Operations provide energy related services. On January 11, 2002, the Company's primary subsidiary engaged in unregulated activities, Avistar, was transferred by way of a dividend to the Holding Company by its subsidiary, PNM.

Financial information relating to amounts of sales, revenue, net income and total assets of the Company's business units or reportable segments is contained in "Part II, Item 7. - Management's Discussion and Analysis of Financial Condition and Results of Operations" and note 2 of the notes to consolidated financial statements.

COMPANY WEBSITE

Upon request the Company will provide free of charge our annual report on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and amendments to those reports filed or furnished pursuant to Section 13(a) or 15(d) of the Exchange Act. These reports are also made available on or through our internet website at www.pnm.com as soon as reasonably practicable after we electronically file material with the SEC. In addition, you should read the following discussion and analysis together with our Consolidated Financial Statements included elsewhere in this report.

1

UTILITY OPERATIONS

Electric

The Company provides jurisdictional retail electric service to a large area of north central New Mexico, including the 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:

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.

Electric procures all of its electric power needs from Generation and Marketing Operations. These intersegment sales are priced using internally developed transfer pricing and are not based on market rates. Customer electric rates are regulated by the PRC and determined on a basis that includes the recovery of the cost of power production by Generation and Marketing Operations and a return on the related assets.

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

2

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 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 48.75% 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 EPNG 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.

3

GENERATION AND MARKETING OPERATIONS

The Company's Generation and Marketing Operations serve four principal markets. Sales to the Company's Utility Operations to cover jurisdictional electric demand and sales to firm-requirements wholesale customers comprise two of these markets. Intersegment sales to the Utility Operations are priced using internally developed transfer pricing and are not based on market rates. The third market consists of other contracted sales to third parties for which Generation and Marketing Operations commit to deliver a specified amount of capacity (measured in megawatts-MW) or energy (measured in megawatt hours-MWh) over a given period of time. The fourth market consists of energy sales from excess capacity made on an hourly basis at fluctuating, spot-market rates. These sales include the Company's wholesale power marketing activities. The Company is connected to the Western area power grid, which includes California and the surrounding states, and therefore its wholesale power sales are into this market. The Western United States wholesale power market in 2000 and 2001 was, and continues to be, extremely volatile due to a power supply shortage and other constraints. (See "Part II, Item 7 - Management's Discussion and Analysis of Financial Condition and Results of Operations - Other Issues Facing the Company
- Western United States Wholesale Power Market.")

Power Sales

A significantly larger portion of the Company's earnings in 2001 and 2000 was derived from its wholesale electric sales than in 2002. However, in the last half of 2001, the wholesale power market in the Western United States became extremely volatile and, while providing many marketing opportunities, presented and continues to present significant risk to companies selling power into this marketplace. In 2002, the Company's revenues from this marketplace declined significantly as a result of a slowdown in the wholesale market. The Company has been successful, however, in developing its wholesale power marketing activities in the Western United States. Management believes this success is due to its niche business strategy of providing electric power customized to meet the special needs of its customers. This niche marketing strategy is based on the Company's asset-backed methodology whereby the Company's net open position is always supported by its generation capacity excluded from its retail rates, or by the availability of power not needed to serve its retail customers. This asset-backed methodology helps to mitigate the risks inherent in the Company's wholesale power marketing activities. The Company also utilizes long-term transactions to enhance its product offering.

Certain Company generation assets are excluded from retail electric rates. In 1988, the NMPUC excluded 130MW of SJGS Unit 4 and all of PVNGS Unit 3. As a result, the Company developed a wholesale power marketing operation to sell the generation from its excluded assets that no longer generated a return in rate base. These activities include the forward purchase and sale of electricity to take advantage of market price opportunities in the electric wholesale market. During 2002, 2001 and 2000, the Company's sales in the wholesale electric markets accounted for approximately 56%, 64% and 64%, respectively, of its total MWh sales. Of the total wholesale electric sales made in 2002, 2001 and 2000, 70%, 77% and 75%, respectively were transacted through purchases for resale.

4

In 1990, the NMPUC established a wholesale electric sales methodology that provided for fixed rate paths within its jurisdiction for predetermined periods with wholesale electric sales accruing to the benefit of shareholders. Subsequent rate cases continued to utilize this methodology. In setting these periodic fixed rate paths, PNM has been able to reduce its jurisdictional electric customers' rates by over $300 million since 1990. On January 28, 2003, the PRC approved the Global Electric Agreement which sets a rate path through 2007. PNM will decrease retail electric rates 6.5% in two phases over the next three years. The first phase of the rate reductions become effective in September 2003. In addition, certain plant and purchased power contracts previously excluded from retail rates are now included as generation resources to serve PNM's New Mexico retail and firm wholesale requirements customers' load. These resources include San Juan Unit 4 and PNM's contracts to purchase power from SPS, Tri-State and Delta. PVNGS Unit 3 remains excluded as are the recently operational Lordsburg and Afton plants. (See "Part II - Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Other Issues Facing the Company - Merchant Plant Filing and Electric Rate Settlement.")

The Generation and Marketing strategy calls for increased asset-backed marketing and generation capacity supported by long-term contracts, balanced with 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 environment has led the Company to scale back its expansion plans, the Company will continue to operate in the wholesale market. 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.

The Company has entered into various firm wholesale electric sales contracts. These contracts contain fixed capacity charges in addition to energy charges. The APPA contract requires APPA to purchase varying amounts of power from the Company through May 2008 and allows APPA to make adjustments to the purchase amounts subject to certain notice provisions. For 2001, APPA invoked its option to increase its peak demand to 92 MW. The APPA demand dropped to 15 MW in June 2002. The Company furnished firm-requirements wholesale power in New Mexico in 2002 to the City of Gallup. The Company is committed to provide service to the City of Gallup through June 2013. Average monthly demands under the City of Gallup contract for 2002 were approximately 29 MW. Beginning July 2000, the Company began serving Navopache Electric Cooperative firm-requirements service under the provisions of a 10-year contract. Average monthly demand for Navopache is 50 MW. The Company began serving a partial requirements contract with the Texas-New Mexico Power Company in July 2001 for 62 MW. The contract service dropped to 32 MW in 2002, then became a firm-requirements contract in January 2003 and continues through 2006. Beginning March 1, 2003, the Company began servicing WAPA for approximately 60 MW of electric power that will be wheeled to serve KAFB. The Company's firm-requirements demand is expected to be 238 MW in 2003, 241 MW in 2004, 232 MW in 2005, 237 MW in 2006 and 241 MW in 2007. No firm-requirements wholesale customer accounted for more than 4.0% of the Company's total electric sales for resale revenues for the year ended December 31, 2002.

5

Sources of Power

As of December 31, 2002, the total net generation capacity of facilities owned or leased by the Company was 1,742 MW, excluding the operating lease discussed below which would bring the total to 1,874 MW. The Company is committed to increasing its utilization of its major generation capacity at SJGS, Four Corners and PVNGS. SJGS is operated by the Company. SJGS's equivalent availability and capacity factor were 89.4% and 85.3% respectively, for the twelve months ended December 31, 2002, as compared to 84.5% and 80.9%, respectively for 2001. Capacity factors for Four Corners and PVNGS were 73.3% and 94.4%, respectively, in 2002, as compared to 86.2% and 87.5%, respectively, in 2001. Four Corners and PVNGS are operated by APS. (See "Item 2. Properties".)

PNM 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 $225 million for construction 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 turbine, 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.

In addition to generating its own power, the Company purchases power in the market. The Company has a power purchase contract with SPS which originally provided for the purchase of up to 200 MW per year and expires in May 2011. The Company may reduce its purchases from SPS by 25 MW annually upon three years notice. The Company provided notice to reduce the purchase by 25 MW in 1999 and by an additional 25 MW in 2000. The Company also is party to a master power purchase and sale agreement with SPS, dated August 2, 1999, pursuant to which the Company has agreed to purchase 72 MW of firm power from SPS from 2002 through 2005. In addition, the Company 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 will be 39 MW. The Company has a PPA with Tri-State for 50 MW through June 30, 2010. In addition, the Company is interconnected with various utilities for economy interchanges and mutual assistance in emergencies.

In 1996, the Company entered into an operating lease agreement for the rights to all the output of the Delta gas-fired generating plant for 20 years. The plant received FERC approval for "exempt wholesale generator" status. The maximum dependable capacity under the lease is 132 MW. In July 2000, the plant went into operation. The gas turbine generating unit is operated by Delta and is located on the Company's retired Person Generating Station site in the COA. The site for the generating unit was chosen, in part, to provide needed benefits to the Company's constrained transmission system. Primary fuel for the gas turbine generating unit is natural gas provided by the Company's Gas operations. In addition, the unit has the capability to utilize low sulfur fuel oil if natural gas is neither available nor cost effective.

6

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 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 would 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 would be sold on the wholesale market, either within New Mexico or outside the state.

Fuel and Water Supply

The percentages of the Company's generation of electricity (on the basis of KWh) fueled by coal, nuclear fuel and gas and oil, and the average costs to the Company of those fuels (in cents per million BTU), during the past three years were as follows:

                       Coal               Nuclear              Gas and Oil
            Percent of    Average  Percent of    Average  Percent of   Average
            Generation      Cost   Generation      Cost   Generation     Cost
            ---------------------  ---------------------  --------------------

2002......     67.7        193.6      30.7         46.0      1.6        326.7
2001......     66.9        179.6      28.4         45.7      4.7        524.5
2000......     68.0        165.3      29.8         45.4      2.2        482.6

The estimated generation mix for 2003 is 68.5% coal, 28.4% nuclear and 3.1% gas and oil. Due to locally available natural gas and oil supplies, the utilization of locally available coal deposits and the generally abundant supply of nuclear fuel, the Company believes that adequate sources of fuel are available for its generating stations into the foreseeable future.

Coal

The coal requirements for the SJGS are being supplied by SJCC, a wholly-owned subsidiary of BHP Billiton, which 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.

In August 2001, the Company and Tucson signed an agreement with SJCC to replace two surface mining operations with a single underground mine located adjacent to the plant. Underground mining is expected to provide a higher quality coal at a lower cost per ton. The new mine will use the longwall mining technique and is expected to ramp to full station supply by the end of the first quarter 2003.

The revised coal contract, entered into as a result of the move to an underground mine, is expected to save the Company between $400 million and $500 million in base fuel cost reductions and avoided coal cost increases over the next 15 years. Besides saving on fuel costs, the cleaner-burning, less abrasive coal is expected to reduce the plant's maintenance and operating expenses. The plant is expected to realize some of the benefits of the higher quality coal in 2003, as the existing surface mines are phased out and the underground mine is brought to full capacity.

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Four Corners is supplied with coal under a fuel agreement between the owners and 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.

Natural Gas

The natural gas used as fuel for the electric generating plant located in COA (Reeves Station and the Delta operating lease) is delivered by Gas. The Company's Generation and Marketing Operations procures its gas supply independently of Gas and contracting with the Utility Operations for transportation services only.

Nuclear Fuel

The fuel cycle for PVNGS is comprised of the following stages:

o the mining and milling of uranium ore to produce uranium concentrates,

o the conversion of uranium concentrates to uranium hexafluoride,

o the enrichment of uranium hexafluoride,

o the fabrication of fuel assemblies,

o the utilization of fuel assemblies in reactors, and

o the storage and disposal of spent fuel.

The PVNGS participants have contracted for uranium concentrates that will meet 100% of requirements for 2003 and 15% of requirements for 2004.

Through conversion services contracts, the PVNGS participants have arranged for uranium conversion services that will meet 100% of requirements for 2003 and 15% of requirements for 2004.

The PVNGS participants have an enrichment services contract that provides 100% of requirements for 2003 and 15% of requirements for 2004.

The PVNGS participants have a new enriched uranium product (EUP) contract that will furnish 85% of PVNGS' requirements for uranium, conversion services, and enrichment services for 2004 and up to 100% of those requirements from 2005 through 2008. This contract could also provide 100% of enrichment services in 2009 and 2010.

In addition, existing contracts will provide 100% of fuel assembly fabrication services until at least 2015 for each PVNGS unit.

Water Supply

Water for SJGS and Four Corners is obtained from the San Juan River. (See "Item 3. - Legal Proceedings- San Juan River Adjudication".) The Company and Tucson have a contract with the USBR ("USBR Contract") for consumption of 16,200 acre feet of water per year for SJGS. The contract expires in 2005. In 2000, the Company signed a twenty-two year contract with Jicarilla, beginning in 2006, for

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the full 16,200 acre feet of water from the Jicarilla supply in Navajo Reservoir ("Jicarilla Contract") that will replace the contract expiring in 2005. The Jicarilla Contract is essentially equivalent to a renewed USBR Contract, the only material difference being that Jicarilla, as opposed to USBR, would be the contract supplier. Jicarilla has contract water in Navajo Reservoir pursuant to a water rights settlement approved by Congress in 1992 and a judicial decree that was entered February 24, 1999. The contract has received all requisite approvals. In addition, the Company was granted the authority to consume 8,000 acre feet of water per year under a state permit that is held by BNCC. BNCC also has committed a portion of those rights to Four Corners through the life of the plant.

Sewage effluent used for cooling purposes in the operation of the PVNGS units is obtained under contracts with certain municipalities in the area. The contracted quantity of effluent exceeds the amount required for the three PVNGS units. The validity of these effluent contracts is the subject of litigation in state court. (See "Item 3. Legal Proceedings - PVNGS Water Supply Litigation".)

The Four Corners region, in which SJGS and Four Corners are located, has been experiencing drought conditions that may affect the water supply for the plants in 2003, as well as later years if adequate moisture is not received in the watershed that supplies the area. USBR is working to assess the adequacy of the water supply under PNM's USBR contract for 16,200 acre feet of water that supplies SJGS. Additionally, various stakeholders in the San Juan Basin, including the New Mexico State Engineer, are evaluating the water rights that might be affected by the drought conditions, including water rights pursuant to the New Mexico state permit that provide 8,000 acre feet of water to SJGS and approximately 28,000 acre feet of water to Four Corners. PNM is assessing alternatives for temporary supplies of water and is working with USBR and area stakeholders to minimize the effect, if any, on operations of the plants. PNM has assessed its situation with regard to the drought and the alternatives available to it and does not believe that its operations will be materially affected at this time. However, PNM cannot forecast the weather situation and its ramifications with any degree of certainty or how regulators and legislators may impact PNM's situation in the future, should the drought continue.

UNREGULATED OPERATIONS

The Company's wholly-owned subsidiary, Avistar, was formed in August 1999 as a New Mexico corporation and is currently engaged in certain unregulated, non-utility business ventures.

In July 2001, the Board of Directors of Avistar decided to wind down operations except for Avistar's Reliadigm business unit, which provides maintenance and productivity improvement solutions to the electric power industry. Avistar had previously divested itself of its Energy Partners business unit and liquidated Axon Field services and Pathways Integration. 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 remaining non-Reliadigm investments were written-off with the exception of a portion of Avistar's investment in Nth Power, an energy venture capital fund. The Company recorded charges of $13.1 million to reflect these activities and the impairment of its Avistar investments in 2001.

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RATES AND REGULATION

PNM is subject to the jurisdiction of the PRC, the successor of the NMPUC effective January 1, 1999, with respect to its retail electric and gas rates, service, accounting, issuance of securities, construction of major new generation and transmission facilities and other matters regarding retail utility services provided in New Mexico. The FERC has jurisdiction over rates and other matters related to wholesale electric sales and cost recovery of its transmission network. The FERC has begun to take more aggressive action with regard to the exercise of its jurisdictional authority over wholesale electric sales. In February 2000, in response in part to the allegations of wrong-doing in the California spot market, the FERC announced it was establishing the Office of Market Oversight and Investigations ("OMOI") as the third prong of its strategic plan. The stated purpose of the FERC OMOI is to engage in the vigilant oversight of energy markets to ensure effective regulation and remediation of market problems, while vigorously enforcing compliance with the FERC's rules and regulations. The FERC has moved forward to staff its OMOI and it is now a fully functioning branch of the FERC.

Electric Rates and Regulation

Restructuring the Electric Utility Industry

See "Part II - Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Restructuring the Electric Utility Industry."

Merchant Plant Filing and Global Electric Agreement

See "Part II - Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Merchant Plant Filing and Global Electric Agreement."

FERC

Mandated Regional Transmission Organizations

With the passage of the Public Utility Regulatory Policies Act of 1978 and the Energy Policy Act of 1992, there has been a significant increase in the level of competition in the market for the generation and sale of electricity. Barriers have been reduced for companies wishing to build, own and operate electric generating facilities. In 1996, the FERC issued Order 888 requiring electric utilities controlling transmission facilities to file open access transmission tariffs, which opened the utility transmission systems to wholesale sellers and buyers of electric energy on a non-discriminatory basis.

Order 888 also encouraged utilities to investigate the formation of independent system operators ("ISOs") to operate transmission assets and provided guidance for the formation, operation and governance of ISOs. In 1999, the FERC issued Order 2000 on Regional Transmission Organizations ("RTOs"), which established timelines for transmission-owning entities to join an RTO and defined the minimum characteristics and functions of an RTO.

The Company, along with other regional transmission owners ("TOs"), originally pursued the formation of an RTO through Desert STAR, a non-profit organization. Because of the FERC's subsequent acceptance of a for-profit RTO model and because a for-profit RTO was viewed as having the proper motivation to efficiently facilitate competitive markets, the Company and the TO's formed WestConnect RTO, LLC ("WestConnect"), a for-profit transmission company.

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On October 16, 2001, WestConnect filed its complete RTO package with FERC requesting a Declaratory Order confirming the WestConnect filing satisfies the FERC Order 2000 requirements. There were over 50 intervenors in the WestConnect docket, including the New Mexico Attorney General, New Mexico Industrial Energy Consumers and the PRC, which filed comments or concerns regarding WestConnect's declaratory order petition. WestConnect filed a response to the intervenors' concerns on December 17, 2001. On October 10, 2002, the FERC issued its Declaratory Order in the case providing guidance and conditions under which the proposal for formation of the WestConnect RTO would be deemed to satisfy the FERC's requirements for RTO status under its Order 2000. Several parties to the proceeding, including PNM as a proposed member of WestConnect, filed motions for rehearing and clarification of the FERC's Declaratory Order. On December 23, 2002, the FERC issued its order granting in part and denying in part the requests for rehearing and provided clarification on certain issues raised by the parties in the case. This order on rehearing provided for certain filings that need to be made by WestConnect's proposed participants in order to move WestConnect forward towards RTO status. PNM is currently evaluating the requirements of the FERC's order on rehearing.

Uncertainty exists regarding the FERC's evolving RTO policy. WestConnect is participating in various workshops and rulemakings before the FERC and is pursuing avenues to expand its scope so as to enhance its chances for approval as one of the RTOs in the West.

El Paso Electric - Afton Generating Station Matter

With the Company's construction of Afton, PNM representatives have been engaged in a FERC proceeding with El Paso to obtain transmission capacity on El Paso's transmission system to transmit 141 MW of power generated at Afton north to serve certain load needs on PNM's system in the COA area. To date, El Paso has executed an agreement to transmit only 30 MW of power on a firm service basis, and offered to supply an additional 20 MW of contingent transmission service. On October 29, 2002, at PNM's request in the FERC proceeding, El Paso filed with the FERC its unexecuted transportation agreements to provide 20 MW of contingent transmission service to PNM. On November 19, 2002, PNM filed its protests with FERC challenging El Paso's denial of PNM's request for the full 141 MW of transmission service. In an order issued by FERC on December 20, 2002, FERC ordered the matter to be set for hearing. The FERC has set the hearing in this matter for July 22, 2003. PNM will participate fully in this matter and aggressively pursue its rights. PNM cannot predict the outcome of this proceeding.

Rulemakings

Over the past year, FERC has issued numerous rulemakings. The Company is following the rulemakings and will submit its comments or will comment in conjunction with the Edison Electric Institute ("EEI"). The WestConnect members are also following, attending workshops and commenting on the rulemakings, which affect the member companies, including PNM. The rulemaking of particular interest to PNM include the Standard Market Design ("SMD") rule, in which the FERC is attempting to remedy what it sees as undue discrimination in the provision of interstate transmission services, and to ensure just and reasonable

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rates for electric energy within and among regional power markets. The proposed rule would put all transmission customers, including bundled retail customers, under new pro forma transmission rates for new transmission service. All transmission will be operated under independent transmission providers (including RTOs) and congestion management will be handled under locational marginal pricing with tradable congestion revenue rights. PNM plans to submit comments on the SMD NOPR along with other WestConnect companies and will continue to participate in the rulemaking process. Other rulemakings that PNM is participating in and in which it has filed comments, either alone or in conjunction with the WestConnect participants, include:

o Standardizing Generation Interconnection Agreements and Procedures;
o Standards of Conduct for Transmission Providers; and
o Standards for Business Practices of Interstate Natural Gas Pipelines.

PRC

Transmission Investigation

In July 2001, the AG filed a petition requesting that the PRC initiate an investigation of electric transmission issues including FERC versus PRC jurisdiction and the effect of RTO formation on PRC jurisdiction. The Company suggested workshops to inform the PRC and other interested parties on the issues. The PRC held workshops for three days, and subsequently issued an order requiring that the Company and other transmission-owning entities in the proceeding file comments on jurisdictional issues. PNM and other New Mexico jurisdictional utilities filed their comments. Subsequently, on December 9, 2002, the AG filed another motion in the case requesting that the New Mexico jurisdictional utilities file updated comments and provide a status on their participation and activities related to the establishment of RTOs, and requested the PRC to issue an order establishing a moratorium on the filing of applications seeking approval for participation in an RTO until May 1, 2003. PNM filed its response on December 23, 2002, suggesting that additional workshops be held to provide stakeholders with an update on RTO participation and activities, and that it did not object to a moratorium on the filing of applications seeking approval for participation in RTOs since it had no current plans to make such a filing before May 2003. The PRC has not yet issued an order in response to the AG's motion. On December 12, 2002, SPS filed an application at the PRC requesting approval of its participation in the TRANSLink RTO. PNM has intervened in this proceeding and plans to fully participate in it.

Renewable Resources Rulemakings

On May 15, 2001, the PRC issued a Notice of Inquiry seeking input as to the need for a rule to encourage the development of renewable energy in New Mexico. Rule 573, includes a provision requiring the use of a minimum of 5% renewable energy by January 1, 2006, with the minimum amount to increase 1% per year for each year until a renewable portfolio standard of 10% is reached in the year 2011. Rule 573 also provides that each kilowatt of electricity generated by solar technology will count as three KWhs and each kilowatt hour generated by bio-mass, geothermal landfill gas, or fuel cell sources will count as two KWhs. All remaining sources of renewable energy, including wind and hydroelectronic technologies, will count as one KWh for each KW generated. On January 16, 2003, the Company filed a request for rehearing asking the PRC to reconsider its final order. By order issued February 4, 2003, the PRC denied all requests for rehearing. PNM is considering the possibility of filing an appeal with the New Mexico Supreme Court seeking to reverse the final order. The New Mexico Legislature is considering legislation that might impact Rule 573. In its present form, Rule 573 could significantly change the make-up of PNM's energy supply portfolio. The Company is unable to predict the outcome of this rulemaking proceeding.

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Gas Rates and Regulation

Gas Rate Case

On January 10, 2003, PNM filed a gas general rate case, which asks the PRC to approve an increase in the service fees charged to its 441,000 natural-gas customers. The proposal would increase both the set monthly service fee and the charge tied to monthly usage. Those fees are separate from the cost of gas charged to customers. The monthly cost of gas charge would not be affected by the fee increase as discussed below. The proposed cost of service rate increase of $37.6 million is designed to provide PNM's gas utility an opportunity to earn a 12 percent return on equity, which is consistent with the return allowed 15 comparable natural gas utilities. PNM's current return on equity from its gas business is below 3%. A hearing of the case is anticipated to begin the last week of June 2003.

Purchase Gas Adjustment Clause

The Company's retail gas rate tariffs contain a PGAC that provides timely recovery for the cost of gas purchased for resale to its sales-service customers. In 2001, the Company presented workshops to the PRC, advocating that the PGAC balancing account be reconciled on a monthly basis, rather than annually. The Company also requested that it be allowed to earn a return on the balancing account balance. A final order was issued in July 2001 that approves an agreement among the parties regarding the Company's hedging strategy and the implementation of a price management fund program which includes a continuous monthly balancing account adjustment factor with a carrying charge set at the pre-tax cost of capital approved by the PRC in the Company's last gas rate proceeding. This carrying charge has the effect of keeping the Company whole on gas purchase transactions since it is now compensated for the time value of money.

Discounted Transportation Fee Recovery

The Company made a request to begin the recovery of discounted transportation fee amounts from sales and transportation customers. Discounted transportation fee recovery is a holdover issue from the New Mexico Supreme Court's ruling that the amounts passing the PRC's cost benefit test were collectible and leaving open only the issue of allocation between customers. The discounts passing the PRC's cost benefit test total $4.4 million. A hearing date of April 17, 2003 has been set.

Notice of Inquiry on Pipeline Safety

In May 2001, the PRC issued a notice of inquiry into whether the PRC should consider adopting new rules, including quality of service standards, to protect the public health and safety, public and private property, and the environment by ensuring the integrity of pipeline systems. The PRC requested information from all pipeline operators with underground or above ground facilities in the state. The Company submitted its comments and participated in the hearings in this inquiry. Subsequent PRC action is pending.

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El Paso Gas Capacity Allocation Matter

In an order issued by FERC on May 31, 2002, as supplemented by an order issued on September 20, 2002, the FERC mandated that all full-requirements customers on EPNG's transmission system, including PNM, convert from their current full requirements natural gas transportation service to contract-demand transportation service by November 1, 2002. Under this new type of service, PNM would be allocated a certain level of transportation capacity on EPNG's transmission system at certain designated receipt points. Several parties have filed petitions for rehearing requesting that FERC reconsider its order requiring the change-over in transportation service. The FERC has subsequently delayed implementing the conversion to contract demand transportation service until May 1, 2003. On December 2, 2002, EPNG filed its proposed capacity allocation report wherein, it purported to assign contract demand capacity at certain receipt points along its system, as well as reallocate costs among full requirements customers. On January 13, 2003, PNM filed comments to EPNG's report objecting to EPNG's proposed reallocation of costs. EPNG's converting customers are engaged in ongoing negotiations regarding the reallocated capacity available for converting shippers and the appropriate cost-reallocation methodology. The costs PNM incurs for obtaining natural gas transportation services are flowed-through in the transportation component of rates charged to retail natural gas customers. PNM is participating in this matter fully to protect its rights, and cannot predict the outcome of this proceeding.

ENVIRONMENTAL MATTERS

The Company, in common with other electric and gas utilities, is subject to stringent laws and regulations for protection of the environment by local, state, Federal and tribal authorities. In addition, PVNGS is subject to the jurisdiction of the NRC, which has authority to issue permits and licenses and to regulate nuclear facilities in order to protect the health and safety of the public from radioactive hazards and to conduct environmental reviews pursuant to the National Environmental Policy Act. Liabilities under these laws and regulations can be material and, in some instances, may be imposed without regard to fault, or may be imposed for past acts, whether or not such acts may have been lawful at the time they occurred. (See "Part II, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Critical Accounting Policies - Contingent Liabilities - Environmental Issues" for a discussion of applicable accounting policies.)

The Clean Air Act

On July 1, 1999, the EPA published its final regional haze regulations. The purpose of the regional haze regulations is to address regional haze visibility impairment in the 156 Class 1 areas in the nation, which consist of national parks, wilderness areas and other similar areas. The final rule calls for all states to establish goals and emission reduction strategies for improving visibility in all the Class 1 areas. The Company cannot predict at this time what the impact of the implementation of the regional haze rule will be on the Company's coal-fired power plant operations. Potentially, additional SO2 emission reductions could be required in the 2013-2018 timeframe. The nature and cost of compliance with these potential requirements cannot be determined at this time. However, the Company does not anticipate any material adverse impact on the Company's financial condition or results of operations.

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Person Station

The Company, in compliance with a Corrective Action Directive issued by the NMED, determined that groundwater contamination exists in the deep and shallow groundwater at the Company's Person Station site. The Company is required to delineate the extent of the contamination and remediate the contaminants in the groundwater at the Person Station site. The extent of shallow and deep groundwater contamination was assessed and the results were reported to the NMED. The Company has received the renewal of the RCRA post-closure care permit for the facility. Remedial actions for the shallow and deep groundwater were incorporated into the new permit. The Company has installed and is operating a pump and treatment system for the shallow groundwater. The renewed RCRA post-closure care permit allows remediation of the deep groundwater contamination through natural attenuation. The Company's current estimate to decommission its retired fossil-fueled plants (discussed below) includes approximately $4.2 million in additional expenses to complete the groundwater remediation program at Person Station. The remediation program continues on schedule.

Retired Fossil-Fueled Plant Decommissioning Costs

The Company's retired fossil-fueled generating stations, Person, Prager and Santa Fe Stations, have incurred dismantling and reclamation costs as they are decommissioned. The Company's share of decommissioning costs for these fossil-fueled generating stations is projected to be approximately $24 million stated in 2002 dollars (of which $18.4 million has already been expended).

New Source Review Rules

See "Part II - Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - New Source Review Rules."

Citizen Suit Under the Clean Air Act

See "Part II - Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Citizen Suit Under the Clean Air Act."

COMPETITION

Under current law, the Company is not in any direct retail competition with any other regulated electric and gas utility, except for sales of natural gas. Nevertheless, the Company is subject to varying degrees of competition in certain territories adjacent to or within areas it serves that are also currently served by other utilities in its region as well as by rural electric cooperatives and municipal utilities.

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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..................................       1,133
Gas Services.......................................         526
Generation and Marketing Operations................         558
Unregulated Operations.............................          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 Services, 244; (ii) Gas Services, 56; and (iii) Generation and Marketing Operations, 340.

ITEM 2. PROPERTIES

ELECTRIC

PNM's ownership and capacity in electric generating stations in commercial service as of December 31, 2002, were as follows:

                                                                  Total Net
                                                                  Generation
                                                                   Capacity
       Type                Name                Location              (MW)
----------------   -----------------   ------------------------  -------------

Coal............   SJGS (a)            Waterflow, New Mexico           765
Coal............   Four Corners (b)    Fruitland, New Mexico           192
Gas/Oil.........   Reeves              Albuquerque, New Mexico         154
Gas/Oil.........   Las Vegas           Las Vegas, New Mexico            20
Gas/Oil.........   Afton               La Mesa, New Mexico             141
Gas.............   Lordsburg           Lordsburg, New Mexico            80
Nuclear.........   PVNGS (c)           Wintersburg, Arizona            390 (d)
                                                                    -------
                                                                     1,742
    Delta Operating Lease (e)                                          132
                                                                    -------
                                                                     1,874
                                                                    =======

(a) SJGS Units 1, 2 and 3 are 50% owned by PNM; SJGS Unit 4 is 38.5% owned by the Company.
(b) Four Corners Units 4 and 5 are 13% owned by PNM.
(c) PNM is entitled to 10.2% of the power and energy generated by PVNGS. PNM has a 10.2% ownership interest in Unit 3 and has leasehold interests in approximately 7.9% of Units 1 and 2 and an ownership interest in approximately 2.3% of Units 1 and 2.
(d) For load and resource purposes, the Company has notified the PRC that it recognizes the maximum dependable capacity rating for PVNGS to be 381 MW.

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(e) The Company has an operating lease for the rights to all output of a gas fired generating plant with maximum dependable capacity of 132 MW.

The Company's owned interests in PVNGS are mortgaged to secure its remaining first mortgage bonds.

Fossil-Fueled Plants

SJGS is located in northwestern New Mexico, and consists of four units operated by PNM. Units 1, 2, 3 and 4 at SJGS have net rated capacities of 327 MW, 316 MW, 497 MW and 507 MW, respectively. SJGS Units 1 and 2 are owned on a 50% shared basis with Tucson. Unit 3 is owned 50% by the Company, 41.8% by SCPPA and 8.2% by Tri-State. Unit 4 is owned 38.457% by the Company, 28.8% by M-S-R, 10.04% by Anaheim, 8.475% by Farmington, 7.2% by Los Alamos and 7.028% by UAMPS.

PNM also owns 192 MW of net rated capacity derived from its 13% interest in Units 4 and 5 of Four Corners located in northwestern New Mexico on land leased from the Navajo Nation and adjacent to available coal deposits. Units 4 and 5 at Four Corners are jointly owned with SCE, APS, Salt River Project, Tucson and El Paso and are operated by APS.

Four Corners and a portion of the facilities adjacent to SJGS are located on land held under easements from the United States and also under leases from the Navajo Nation. The enforcement of these leases could require Congressional consent. The Company does not deem the risk with respect to the enforcement of these easements and leases to be material. However, the Company is dependent in some measure upon the willingness and ability of the Navajo Nation to protect these properties.

The Company owns 154 MW of generation capacity at Reeves Station in COA and 20 MW of generation capacity at Las Vegas Station in Las Vegas, New Mexico. During 2002, the Company added Afton, a 141 MW gas or oil fired combustion turbine plant in La Mesa, New Mexico, and Lordsburg, an 80 MW of gas fired combustion turbine generator in Lordsburg, New Mexico. In addition, the Company has 132 MW of generation capacity in COA under an operating lease. These power sources are used primarily for peaking and transmission support. During times of excess capacity, resources have been used to augment the Company's wholesale power trading activities.

Nuclear Plant

The Company's Interest in PVNGS

The Company is participating in the three 1,270 MW units of PVNGS, also known as the Arizona Nuclear Power Project, with APS (the operating agent), Salt River Project, El Paso, SCE, SCPPA and the Department of Water and Power of the City of Los Angeles. The Company has a 10.2% undivided interest in PVNGS, with portions of its interests in Units 1 and 2 held under leases.

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Nuclear Safety Performance Rating on PVNGS

In 2000, the NRC began using a new, objective oversight process that is more focused on safety. The new process includes objective performance thresholds based on insights from safety studies and 30 years of plant operating experience in the United States. It is more timely to move from the 18 to 24-month time lag of the previous oversight process for assessing plant performance to a quarterly review. The NRC also hopes the process will be more accessible to, and readily understood by, the public. In its most recent review, PVNGS had all 38 indicators green (the best possible of the four indicator levels).

Sale and Leaseback Transactions of PVNGS Units 1 and 2

In 1985 and 1986, the Company entered into a total of eleven sale and lease back transactions with owner trusts under which it sold and leased back its entire 10.2% interest in PVNGS Units 1 and 2, together with portions of the Company's undivided interest in certain PVNGS common facilities. The leases under each of the sale and leaseback transactions have initial lease terms expiring January 15, 2015 (with respect to the Unit 1 leases) or January 15, 2016 (with respect to the Unit 2 leases). Each of the leases allows the Company to extend the term of the lease as well as includes a repurchase option. The lease expense for the Company's PVNGS leases is approximately $66.3 million per year. Throughout the terms of the leases, the Company continues to have full and exclusive authority and responsibility to exercise and perform all of the rights and duties of a participant in PVNGS under the Arizona Nuclear Power Project Participation Agreement and retains the exclusive right to sell and dispose of its 10.2% share of the power and energy generated by PVNGS Units 1 and 2. The Company also retains its responsibility to pay of its share of all taxes, insurance premiums, operating and maintenance costs, costs related to capital improvements and decommissioning and all other similar costs and expenses associated with the leased facilities. In 1992, the Company purchased approximately 22% of the beneficial interests in the PVNGS Units 1 and 2 leases through the purchase of ownership interest in the trusts which held the leases. The related ownership interests were subsequently reacquired by the Company when the Company's trust ownership was collapsed and the Company assumed direct ownership. In connection with the $30 million retail rate reduction approved by the NMPUC in 1994, the Company wrote down the purchased beneficial interests in PVNGS Units 1 and 2 leases to $46.7 million.

Each lease describes certain events, "Events of Loss" or "Deemed Loss Events", the occurrence of which could require the Company to, among other things, (i) pay the lessor and the equity investor, in return for the investor's interest in PVNGS, cash in the amount provided in the lease and (ii) assume debt obligations relating to the PVNGS lease. The "Events of Loss" generally relate to casualties, accidents and other events at PVNGS, which would severely, adversely affect the ability of the operating agent, APS, to operate, and the ability of the Company to earn a return on its interests in, PVNGS. The "Deemed Loss Events" consist mostly of legal and regulatory changes (such as changes in law making the sale and leaseback transactions illegal, or changes in law making the lessors liable for nuclear decommissioning obligations). The Company believes the probability of such "Events of Loss" or "Deemed Loss Events" occurring is remote for the following reasons: (i) to a large extent, prevention of "Events of Loss" and some "Deemed Loss Events" is within the control of the PVNGS participants, including the Company, and the PVNGS operating agent, through the general PVNGS operational and safety oversight process and (ii) with respect to other "Deemed Loss Events," which would involve a significant change in current law and policy, the Company is unaware of any pending proposals or proposals being considered for introduction in Congress, or in any state legislative or regulatory body that, if adopted, would cause any such events.

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Other PVNGS Matters

See Note 12 in the notes to the consolidated financial statements for information on PVNGS Decommissioning Funding, Nuclear Spent Fuel and Waste Disposal and PVNGS Liability and Insurance Matters.

Other Electric Properties

As of December 31, 2002, the Company owned, jointly owned or leased, 2,897 circuit miles of electric transmission lines, 4,258 miles of distribution overhead lines, 3,945 cable miles of underground distribution lines (excluding street lighting) and 247 substations.

NATURAL GAS

The natural gas properties as of December 31, 2002, consisted primarily of natural gas storage, transmission and distribution systems. Provisions for storage made by the Company include ownership and operation of an underground storage facility located near Albuquerque, New Mexico. The transmission systems consisted of approximately 1,555 miles of pipe with appurtenant compression facilities. The distribution systems consisted of approximately 11,367 miles of pipe.

OTHER INFORMATION

The electric and gas transmission and distribution lines are generally located within easements and rights-of-way on public, private and Indian lands. The Company leases interests in PVNGS Units 1 and 2 and related property, EIP and associated equipment, data processing, communication, office and other equipment, office space, utility poles (joint use), vehicles and real estate. The Company also owns and leases service and office facilities in Albuquerque and in other areas throughout its service territory.

ITEM 3. LEGAL PROCEEDINGS

Navajo Nation Environmental Issues

Four Corners is located on the Navajo Reservation and is held under an easement granted by the federal government as well as a lease from the Navajo Nation. APS is the Four Corners operating agent and PNM owns a 13% ownership interest in Units 4 and 5 of Four Corners.

In July 1995, the Navajo Nation enacted the Navajo Nation Air Pollution Prevention and Control Act, the Navajo Nation Safe Drinking Water Act, and the Navajo Nation Pesticide Act (collectively, the "Navajo Acts"). The Navajo Acts purport to give the Navajo Nation Environmental Protection Agency authority to promulgate regulations covering air quality, drinking water, and pesticide activities, including those that occur at Four Corners. The Four Corners participants dispute that purported authority, and by letter dated October 12, 1995, the Four Corners participants requested the United States Secretary of the Interior to resolve their dispute with the Navajo Nation regarding whether or not the Navajo Acts apply to operations of Four Corners. On October 17, 1995, the Four Corners participants filed a lawsuit in the District Court of the Navajo Nation, Window Rock District, seeking, among other things, a declaratory judgment that:

19

o the lease and federal easement preclude the application of the Navajo Acts to the operations of Four Corners; and

o the Navajo Nation and its agencies and courts lack adjudicatory jurisdiction to determine the enforceability of the Navajo Acts as applied to Four Corners.

On October 18, 1995, the Navajo Nation and the Four Corners participants agreed to indefinitely stay these proceedings so that the parties may attempt to resolve the dispute without litigation. The Secretary and the Court have stayed these proceedings pursuant to a request by the parties. The Company cannot currently predict the outcome of this matter.

In February 1998, the EPA issued regulations identifying those Clean Air Act provisions for which it is appropriate to treat Indian tribes in the same manner as states. The EPA has announced that it has not yet determined whether the Clean Air Act would supersede pre-existing binding agreements between the Navajo Nation and the Four Corners participants that could limit the Navajo Nation's environmental regulatory authority over Four Corners. The Company believes that the Clean Air Act does not supersede these pre-existing agreements. The Company cannot currently predict the outcome of this matter.

On August 8, 2000, the EPA signed an Eligibility Determination for the Navajo Nation for Grants Under Section 105 of the Clean Air Act in which the EPA determined that the Navajo Nation was eligible to receive grants under the Clean Air Act. On September 8, 2001, after learning of the eligibility determination, APS, as Four Corners operating agent, filed a Petition for Review of the EPA's decision in the United States Court of Appeals for the Ninth Circuit in order to ensure that the EPA's August 2000 determination not be construed to constitute a determination of the Navajo Nation's authority to regulate Four Corners. APS, the EPA and other parties have requested that the Court stay any further briefing while they negotiate a settlement.

In April 2000, the Navajo Tribal Council approved operating permit regulations under the Navajo Nation Air Pollution Prevention and Control Act. The Four Corners participants believe that the regulations fail to recognize that the Navajo Nation did not intend to assert jurisdiction over Four Corners. On July 12, 2000, the Four Corners participants each filed a petition with the Navajo Supreme Court for review of the operating permit regulations. The Company cannot currently predict the outcome of this matter.

KAFB Contract

In 1999, PNM was informed that the DOE had entered into an agency agreement with WAPA on behalf of KAFB, one of PNM's largest retail electric customers, by which WAPA would competitively procure power for KAFB. The proposed wholesale power procurement was to begin at the expiration of KAFB's power service contract with the Company in December 1999. On May 4, 1999, PNM received a request for network transmission service from WAPA pursuant to
Section 211 of the Federal Power Act to facilitate the delivery of wholesale power to KAFB over PNM's transmission system. PNM denied WAPA's request. On October 1, 1999, WAPA filed a petition requesting the FERC to order PNM to provide network transmission service to WAPA on behalf of DOE and several other entities located on KAFB under PNM's Open Access Transmission Tariff. The petition claimed KAFB is a wholesale customer of the Company, not a retail customer.

20

After a number of proceedings with the FERC and an appeal by PNM to the United States Court of Appeals for the Tenth Circuit, PNM, USEA and WAPA settled the dispute. WAPA agreed to purchase from PNM approximately 60 MW of electric power that will be wheeled to serve KAFB. The power sales agreement between PNM and WAPA was executed on February 3, 2003. On March 1, 2003 the power sales agreement went into effect, and PNM dismissed its appeal at the Tenth Circuit on March 5, 2003.

In a related PRC proceeding, a status conference is scheduled on April 1, 2003 to determine how to proceed with the PRC case due to the dismissal of the Tenth Circuit appeal and implementation of the power sales agreement between WAPA and PNM.

PVNGS Water Supply Litigation

The Company understands that a summons served on APS in 1986 required all water claimants in the Lower Gila River Watershed of Arizona to assert any claims to water on or before January 20, 1987, in an action pending in the Maricopa County Superior Court. PVNGS is located within the geographic area subject to the summons and the rights of the PVNGS participants, including the Company, to the use of groundwater and effluent at PVNGS are potentially at issue in this action. APS, as the PVNGS project manager, filed claims that dispute the court's jurisdiction over the PVNGS participants' groundwater rights and their contractual rights to effluent relating to PVNGS and, alternatively, seek confirmation of those rights. In November 1999, the Arizona Supreme Court issued a decision confirming that certain groundwater rights may be available to the federal government and Indian tribes. APS and other parties have petitioned the United States Supreme Court for review of this decision and the petition was denied. In addition, the Arizona Supreme Court issued a decision in September 2000 affirming the lower court's criteria for resolving groundwater claims. APS and other parties filed motions for reconsideration on one aspect of that decision. Those motions have been denied by the Arizona Supreme Court. APS and other parties petitioned the United States Supreme Court for review of the Arizona Supreme Court's decision affirming the lower court's criteria for resolving groundwater claims, and that petition was denied. The Company is unable to predict the outcome of this case.

San Juan River Adjudication

In 1975, the State of New Mexico filed an action entitled "State of New Mexico v. United States, et al.", in the District Court of San Juan County, New Mexico, to adjudicate all water rights in the "San Juan River Stream System". The Company was made a defendant in the litigation in 1976. The action is expected to adjudicate water rights used at Four Corners and at SJGS. (See "Item
1. Business - Generation and Marketing Operations - Fuel and Water Supply - Water Supply.") The Company cannot at this time anticipate the effect, if any, of any water rights adjudication on the present arrangements for water at SJGS and Four Corners. It is the Company's understanding that final resolution of the case cannot be expected for several years. The Company is unable to predict the ultimate outcome.

21

Natural Gas Royalties Qui Tam Litigation

On June 28, 1999, a complaint was served on the Company alleging violations of the False Claims Act by the Company and its subsidiaries, Gathering Company and Processing Company (collectively, the "Company" for purposes of this discussion), by purportedly failing to properly measure natural gas from Federal and tribal properties in New Mexico, and consequently, underpaying royalties owed to the Federal government. A private relator is pursuing the lawsuit. The complaint was served after the United States Department of Justice declined to intervene to pursue the lawsuit. The complaint seeks actual damages, treble damages, costs and attorneys fees, among other relief.

This case was consolidated for pretrial purposes with approximately 70 others, asserting similar claims against other defendants in other jurisdictions, and transferred to Federal District Court for the District of Wyoming by the Federal Multi-District Litigation panel (MDL Panel), recaptioned as "In re: Natural Gas Royalties Qui Tam Litigation, MDL Docket No. 1293." PNM, along with 250 other defendants, filed a motion to dismiss the complaint for failure to plead properly in November 1999. On May 18, 2001, the Wyoming court denied defendants' motion to dismiss the complaint.

While the government has chosen not to participate in the case as a plaintiff, on July 20, 2000 it did file a motion to dismiss certain allegations in the complaint. The motion was limited in its scope to allegations relating to royalty valuation and did not address any of the allegations of gas mismeasurement. The government's motion was granted on October 9, 2002 and the relator has subsequently amended the complaint to remove the royalty valuation allegations.

Currently the parties are engaged in discovery on the issue of whether the relator meets the requirements for bringing a claim under the False Claims Act. The Company expects to participate with other defendants in a motion to dismiss on the ground that the relator does not meet those requirements.

The Company is vigorously defending this lawsuit and is unable to estimate the potential liability, if any, or to predict the ultimate outcome of this lawsuit.

Santa Fe Generating Station ("Santa Fe Station")

PNM and the NMED conducted investigations of the gasoline and chlorinated solvent groundwater contamination detected beneath PNM's former Santa Fe Station site to determine the source of the contamination pursuant to a 1992 Settlement Agreement ("Settlement Agreement") between PNM and the NMED. No source of gasoline contamination in the groundwater was identified as originating from the site. However, in June 1996, PNM received a letter from the NMED, indicating that the NMED believed PNM is the source of gasoline contamination in a City of Santa Fe municipal supply well and in groundwater underlying the Santa Fe Station site. Further, the NMED letter stated that PNM was required to proceed with interim remediation of the contamination pursuant to the New Mexico Water Quality Control Commission regulations. In October 1996, PNM and the NMED signed an amendment to the Settlement Agreement concerning the groundwater contamination underlying the site. As part of the amendment, PNM agreed to spend approximately $1.2 million for certain costs related to sampling, monitoring and the development and implementation of a remediation plan with respect to gasoline contamination in the groundwater.

22

The amended Settlement Agreement does not, however, provide PNM with a full release from potential further liability for remediation of the gasoline contamination in the groundwater. After PNM has expended the settlement amount, if the NMED can establish through binding arbitration that the Santa Fe Station is the source of the contamination, PNM could be required to perform further remediation that is determined to be necessary. PNM continues to dispute any contention that the Santa Fe Station is the source of the gasoline contamination in the groundwater and believes that insufficient data exists to identify the source(s) of the groundwater contamination. PNM's aquifer characterization and groundwater quality reports compiled from 1996 through 2002 strongly suggest groundwater contamination has been drawn under the site by the pumping of the Santa Fe supply well. PNM and the NMED, with the cooperation of the City of Santa Fe, jointly selected a 3 to 4 year remediation plan proposed by a remediation contractor. The City of Santa Fe, PNM and the NMED entered into a memorandum of understanding concerning the selected remediation plan and the operation of the municipal well adjacent to the Santa Fe Station site in connection with carrying out the plan. On October 5, 1998, a new system began operation to treat groundwater produced by the Santa Fe well to drinking water standards for municipal distribution and bioremediation of gasoline contamination beneath the Santa Fe Station site. Since the reactivation of the Santa Fe well, the groundwater treatment and bioremediation systems have resulted in a marked reduction in contaminant concentrations at the wellhead. However, contaminant concentrations at the property boundary remain high.

By letter dated August 7, 2002, PNM provided written notice to the NMED and the City of Santa Fe that PNM had satisfied its obligations with respect to the gasoline contamination under the amended Settlement Agreement, and PNM also stated its intention to cease operation, effective October 5, 2002, of the wellhead and bioremediation systems, and to discontinue monitoring and reporting with respect to gasoline contamination at the site. The NMED responded with a written notice of determination dated August 16, 2002, stating that PNM is the responsible party for gasoline contamination at the site and requested that PNM refrain from cessation of operation of the remediation systems, monitoring and reporting. In a meeting held on September 5, 2002, the NMED indicated its intention to file a court action seeking an order invalidating the binding arbitration provisions of the amended Settlement Agreement and a declaratory judgment that PNM is the responsible party for the gasoline contamination at the site. PNM, the NMED and the City of Santa Fe have entered into a tolling agreement whereby the parties agreed to refrain from filing any actions or invoking the dispute resolution provisions under the Settlement Agreement pending further data review and negotiation with respect to the NMED's determination. The tolling agreement expired on March 5, 2003. As part of the tolling agreement, PNM agreed to continue operation of the wellhead treatment system at the site and to continue well monitoring and reporting to the NMED through October 5, 2003. The Company cannot predict the outcome of these negotiations with NMED.

Former AG&E Manufactured Gas Plant Site

On December 8, 1999, PNM received a letter from the NMED notifying PNM that it had been designated as a "responsible person" under the New Mexico Water Quality Control abatement regulations. PNM was directed to submit an abatement plan to investigate alleged contamination detected in the vicinity of a former manufactured gas plant ("MGP") owned and operated by AG&E in southeast Albuquerque. The contamination identified in the December 8 letter was described as "tar" and "Volatile Organic Compounds." PNM agreed to conduct voluntary abatement.

23

PNM submitted its voluntary stage 1 abatement plan to the NMED on August 31, 2000. By letter dated November 30, 2000, the NMED conditionally approved PNM's voluntary stage 1 abatement plan. PNM submitted its voluntary stage 1 abatement plan report ("Report") on October 12, 2001. The Report confirmed the presence of soil contamination at the site resulting from the operations of the former MGP. By letter dated December 20, 2001, the NMED approved the Report and directed PNM to submit a voluntary stage 2 abatement plan for corrective action at this site. PNM submitted its voluntary stage 2 abatement plan on November 12, 2002 and has selected a remedial alternative and contractor. PNM is currently seeking approvals from regulatory and community groups for the proposed remedial alternative. NMED has indicated that groundwater does not appear to have been impacted by the former MGP operations although groundwater beneath the site contains contaminants consistent with known upgradient diesel sources. Soils at the site contaminated with oil and tar-like materials are proposed for excavation and disposal. Residual contaminants below 15-feet will be capped. The current property owner proposes to construct a two story building at the site in 2003. Completion of remedial activities is anticipated for second quarter 2003.

Citizen Suit Under the Clean Air Act

See "Part II - Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Citizen Suit Under the Clean Air Act".

Landowner Environmental Claims

See "Part II - Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Landowner Environmental Claims".

California Attorney General Complaint

See "Part II - Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Other Issues Facing the Company - Western United States Wholesale Power Market - California Attorney General Complaint".

California Antitrust Litigation

See "Part II - Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Other Issues Facing the Company - Western United States Wholesale Power Market - California Antitrust Litigation".

(Intentionally left blank)

24

ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS

None.

SUPPLEMENTAL ITEM. EXECUTIVE OFFICERS OF PNM RESOURCES

Executive officers, their ages, offices held with PNM Resources since December 31, 2001 (effective date of the Holding Company):

       Name             Age                Office                                  Initial Effective Date
       ----             ---                ------                                  ----------------------

J. E. Sterba..........   47 Chairman, President and Chief Executive
                               Officer                                                 December 31, 2001

R. J. Flynn...........   60 Executive Vice President and Chief
                               Operating Officer                                           July 23, 2002
                            Executive Vice President, Electric and Gas
                               Services                                                December 31, 2001

A. A. Cobb............   55 Senior Vice President, Peoples Services and
                               Development                                             December 31, 2001

J. R. Loyack..........   39 Senior Vice President, and Chief
                               Financial Officer                                         January 1, 2003
                            Vice President, Controller and
                               Chief Accounting Officer                                December 31, 2001

M. H. Maerki..........   62 Senior Vice President, Corporate Strategy
                               and Development and President and
                               Chief Executive Officer, Avistar, Inc.                    January 1, 2003
                            Senior Vice President and Chief Financial
                               Officer and President and Chief
                               Executive Officer, Avistar, Inc.                        December 31, 2001

P. T. Ortiz...........   52 Senior Vice President, General Counsel
                               and  Secretary                                          December 31, 2001

E. Padilla, Jr........   49 Senior Vice President, Bulk Power
                               Marketing and Development                               December 31, 2001

W.J. Real.............   54 Senior Vice President, Public Policy                           July 23, 2002
                            Executive Vice President, Power Production
                               and Marketing                                           December 31, 2001

R. A. Lumney..........   36 Vice President, Controller and Chief
                               Accounting Officer                                        January 1, 2003

(See Public Service Company of New Mexico on pages 26-27 for prior positions held).

All officers are elected annually by the Board of Directors of the Holding Company.

25

EXECUTIVE OFFICERS OF PUBLIC SERVICE COMPANY OF NEW MEXICO

Executive officers, their ages, offices held with Public Service Company of New Mexico in the past five years, (or other companies if less than five years with PNM) and initial effective dates thereof, except as otherwise noted:

       Name             Age                Office                              Initial Effective Date
       ----             ---                ------                              ----------------------

J. E. Sterba........    47 Chairman, President and Chief Executive
                              Officer                                               October 1, 2000
                           President and Chief Executive Officer                       June 6, 2000
                           President                                                  March 1, 2000
                           Executive Vice President, USEC, Inc.                   December 31, 1998
                           Executive Vice President and Chief
                              Operating Officer (of the Company)                     March 11, 1997
                           Senior Vice President, Bulk Power Services
                              (of the Company)                                     December 6, 1994

R. J. Flynn.........    60 Executive Vice President and Chief
                              Operating Officer                                       July 23, 2002
                           Executive Vice President, Electric and Gas
                              Services                                             January 18, 1999
                           Senior Vice President, Electric Services                December 1, 1994

A. A. Cobb..........    55 Senior Vice President, Peoples Services and
                              Development                                        September 11, 2001
                           Global Human Resources Officer,
                              Clientlogic                                         November 22, 1999
                           Executive Vice President, Human
                              Resources, Aames Financial                           February 2, 1999
                           Senior Vice President, Human Resources,
                              Aames Financial                                      November 1, 1996

J. R. Loyack........    39 Senior Vice President, and Chief
                              Financial Officer                                     January 1, 2003
                           Vice President, Controller and
                              Chief Accounting Officer                                July 19, 1999
                           Director, Financial Reporting,
                              Union Pacific Corporation                             October 1, 1998
                           Senior Manager, Business Analysis,
                              Union Pacific Corporation                             January 1, 1996

P. T. Ortiz.........    52 Senior Vice President, General Counsel
                              and Secretary                                         August 10, 1999
                           Senior Vice President and General Counsel               January 18, 1999
                           Senior Vice President, Regulatory Policy,
                              General Counsel and Secretary                        December 7, 1993

26

       Name             Age                Office                                  Initial Effective Date
       ----             ---                ------                                  ----------------------
M. H. Maerki.........    62 Senior Vice President, Corporate Strategy
                               and Development and President and
                               Chief Executive Officer, Avistar, Inc.                   January 1, 2003
                            Senior Vice President and Chief Financial Officer,
                               and President and Chief Executive Officer,
                               Avistar, Inc.                                         September 14, 2001
                            Senior Vice President and Chief Financial
                               Officer                                                 December 7, 1993

E. Padilla, Jr.......    49 Senior Vice President, Bulk Power
                               Marketing and Development                               February 8, 2000
                            Vice President, Bulk Power Marketing
                               and Development                                        December 14, 1996

W. J. Real...........    54 Senior Vice President, Public Policy                          July 23, 2002
                            Executive Vice President, Power
                               Production and Marketing                                January 18, 1999
                            Senior Vice President, Gas Services                        December 6, 1994

R. A. Lumney.........    36 Vice President, Controller and Chief
                               Accounting Officer                                       January 1, 2003
                            Vice President and Corporate Controller
                               Global Crossing Development Co.                        February 19, 2001
                            Director of Accounting
                               Global Crossing Development Co.                           August 6, 1999
                            Senior Manager
                               Arthur Andersen LLP                                         July 1, 1995
---------------------

The President is elected annually by the Holding Company Board of Directors. All other officers are elected annually by the Board of Directors of PNM.

(Intentionally left blank)

27

PART II

ITEM 5. MARKET FOR THE COMPANY'S COMMON EQUITY AND RELATED

STOCKHOLDER MATTERS

The Company's common stock is traded on the New York Stock Exchange. Ranges of sales prices of the Company's and its predecessor's common stock, reported as composite transactions (Symbol: PNM), and dividends declared on the common stock for 2002 and 2001, by quarters, are as follows:

                                                Range of
Quarter Ended                             Sales Prices           Dividends
----------------------             --------------------------
                                       High          Low         Per Share
                                   --------------------------  --------------

2002
   December 31 ...................    24.67        17.47           $0.22
   September 30 ..................    24.33        17.25            0.22
   June 30 .......................    30.55        23.30            0.22
   March 31 ......................    30.76        25.33            0.22
                                                                   -----
     Fiscal Year .................    30.76        17.25           $0.88
                                                                   =====

2001
   December 31 ...................    28 17/25     24 7/20         $0.20
   September 30 ..................    33 11/20     24 18/25         0.20
   June 30 .......................    37 4/5       28 7/10          0.20
   March 31 ......................    29 7/20      22 7/8           0.20
                                                                   -----
     Fiscal Year .................    37 4/5       22 7/8          $0.80
                                                                   =====

On December 10, 2002, the Company's Board of Directors ("Board") declared a quarterly cash dividend of $0.22 per share of common stock payable February 14, 2003, to shareholders of record as of February 3, 2003.

On January 31, 2003, there were 15,046 holders of record of the Company's common stock.

See "Part II. Item 7. Management's Discussion and Analysis of Results of Operations and Financial Condition - Liquidity and Capital Resources - Dividends", for a discussion on the payment of future dividends.

(Intentionally left blank)

28

Cumulative Preferred Stock

While isolated sales of PNM's cumulative preferred stock have occurred in the past, PNM is not aware of any active trading market for its cumulative preferred stock. Quarterly cash dividends were paid on PNM's cumulative preferred stock at the stated rates during 2002 and 2001.

ITEM 6. 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............................  $1,168,996      $2,339,817     $1,611,274     $1,157,543     $1,092,445
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 its Energy Services Business Unit in 1998, certain prior year amounts have been reclassified as discontinued operations.

29

ITEM 7. 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 merchant, PNM markets excess production from the utility, as well as unregulated generation, into a competitive marketplace. The Company also has an electric power marketing operation focused on purchasing wholesale electricity

30

in the open market for future resale or to provide energy to jurisdictional customers in New Mexico when the Company's generation assets cannot satisfy demand. The marketing operations utilize an asset-backed marketing strategy, whereby the Company's aggregate net open position for the sale of electricity is covered by the Company's excess generation capabilities.

As it currently operates, the Company's principal business segments are Utility Operations, which include Electric Services ("Electric") and Gas Services ("Gas"), and Generation and Marketing Operations ("Generation and Marketing"). Electric consists of two major business lines that include distribution and transmission. The transmission business line does not meet the definition of a segment due to its immateriality and is combined with the distribution business line for disclosure purposes. Unregulated Operations provide energy related services.

The Electric and Gas Services 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 Generation and Marketing strategy calls for increased asset-backed marketing and generation capacity supported by long-term contracts, balanced with 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 environment has led the Company to scale back its expansion plans, the Company will continue to operate in the wholesale market. 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.

(Intentionally left blank)

31

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 an operating income growth of 5.3%. This growth came from a combination of load growth and cost savings, demonstrating the balance the regulated utility provides in the Company's "merchant utility" strategy.

Earnings in 2002 and 2001 were affected by certain non-recurring gains and charges. These special items are detailed in the individual business segment discussions below. The following table enumerates these non-recurring charges and shows their effect on diluted earnings per share, in thousands, except per share amounts.

                                                           2002                           2001
                                                ----------------------------  ------------------------------
                                                                   EPS                             EPS
                                                  Earnings      (Diluted)        Earnings       (Diluted)
                                                -------------- -------------  --------------- --------------
Net Earnings Available for Common
   Shareholders...............................       $63,686         $1.61         $149,847          $3.77
                                                -------------- -------------  --------------- --------------
Adjustment for Special (Gains) and Charges
  (net of income tax effects):
  Realignment costs...........................         5,337          0.14              -               -
  Transmission line project write-off.........         2,911          0.07              -               -
  PVNGS and Four Corners severance costs......           942          0.03
  Contribution to PNM Foundation..............             -             -            3,021           0.08
  Nonrecoverable coal
    mine decommissioning costs................             -             -            7,840           0.20
  Write-off of Avistar investments............             -             -            7,907           0.20
  Western Resources acquisition and
    legal costs...............................        (1,471)        (0.04)          10,859           0.27
                                                -------------- -------------   -------------- --------------
    Total.....................................         7,719          0.20           29,627           0.75
                                                -------------- -------------   -------------- --------------
Net Earnings Available For Common
   Shareholders Excluding Special Gains
   and Charges                                       $71,405         $1.81        $179,474           $4.52
                                                ============== =============   =============  ==============

To adjust reported net earnings and diluted earnings per share to exclude the non-recurring gains and charges, gains, net of income tax expense, are subtracted from reported net earnings under GAAP, and charges, net of income tax benefit, are added back to reported net earnings under GAAP.

32

The following discussion is based on the financial information presented in the Consolidated Financial Statements - Segment Information note in the Notes to Consolidated Financial Statements.

Utility Operations

Electric

The table below sets forth the operating results for the Electric business segment.

                                                    Year Ended December 31,
                                             --------------------------------------
                                                   2002                 2001               Variance
                                             -----------------    -----------------    ------------------
                                                                   (In thousands)
Operating revenues:
  External customers.......................        $ 570,089            $ 559,226              $ 10,863
  Intersegment revenues....................              707                  707                     -
                                             -----------------    -----------------    ------------------
  Total revenues...........................          570,796              559,933                10,863
                                             -----------------    -----------------    ------------------
Cost of energy sold........................            3,888                5,102                (1,214)
Intersegment purchases.....................          348,935              341,608                 7,327
                                             -----------------    -----------------    ------------------
  Total cost of energy.....................          352,823              346,710                 6,113
                                             -----------------    -----------------    ------------------
Gross margin...............................          217,973              213,223                 4,750
                                             -----------------    -----------------    ------------------
Administrative and other...................           52,660               48,821                 3,839
Depreciation and amortization..............           34,025               32,666                 1,359
Transmission and distribution costs........           34,236               37,376                (3,140)
Taxes other than income taxes..............           12,482               12,336                   146
Income taxes...............................           24,121               24,607                  (486)
                                             -----------------    -----------------    ------------------
  Total non-fuel operating expenses........          157,524              155,806                 1,718
                                             -----------------    -----------------    ------------------
Operating income...........................         $ 60,449             $ 57,417              $  3,032
                                             -----------------    -----------------    ------------------

Operating revenues increased $10.9 million or 1.9% for the period to $570.8 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.

33

The following table shows electric revenues by customer class and average customers:

                        Electric Revenues
                         (In thousands)

                                                  Year Ended
                                                 December 31,
                                           --------------------------
                                              2002          2001
                                           ------------  ------------
Residential..........................         $ 197,174     $ 187,600
Commercial...........................           247,800       242,372
Industrial...........................            82,009        82,752
Other................................            43,813        47,209
                                           ------------  ------------
                                              $ 570,796     $ 559,933
                                           ============  ============
Average customers....................           384,478       377,589
                                           ============  ============

The following table shows electric sales by customer class:

                         Electric Sales
                        (Megawatt hours)

                                                  Year Ended
                                                 December 31,
                                              2002          2001
                                           ------------  ------------
Residential..........................         2,298,542     2,197,889
Commercial...........................         3,254,576     3,213,208
Industrial...........................         1,612,723     1,603,266
Other................................           240,665       240,934
                                           ------------  ------------
                                              7,406,506     7,255,297
                                           ============  ============

The gross margin, or operating revenues minus cost of energy sold, increased $4.8 million or 2.2%, which reflects the increased energy sales. Electric exclusively purchases power from Generation and Marketing at internally developed prices, which are not based on market rates. These intercompany revenues and expenses are eliminated in the consolidated results.

Total non-fuel operating expenses increased $1.7 million or 1.1%. Administrative and other costs increased $3.8 million or 7.9% due to higher allocated corporate administrative costs of $5.7 million, partially offset by lower bad debt expense of $1.5 million as a result of collection improvements and the absence of losses from the bankruptcy of a significant customer in 2001. Depreciation and amortization increased $1.4 million or 4.2% for the year due to the purchase of transmission plant assets in early 2002. Transmission and distribution costs decreased $3.1 million or 8.4% primarily due to maintenance performed in 2001 to improve system reliability, which did not recur in 2002. Income taxes, which include taxes associated with interest charges, decreased $0.5 million or 2.0% due to lower pre-tax income.

34

Gas

The table below sets forth the operating results for the Gas business segment.

                                                              Gas
                                                    Year Ended December 31,
                                             ---------------------------------------
                                                   2002                  2001             Variance
                                             ------------------    -----------------   ----------------
                                                                  (In thousands)
Operating revenues.........................         $ 272,118            $ 385,418          $(113,300)
Total cost of energy.......................           139,045              251,296           (112,251)
                                             ------------------    -----------------   ----------------
Gross margin...............................           133,073              134,122             (1,049)
                                             ------------------    -----------------   ----------------
Administrative and other...................            53,012               53,093                (81)
Depreciation and amortization..............            20,964               21,465               (501)
Transmission and distribution costs........            29,306               31,072             (1,766)
Taxes other than income taxes..............             7,793                6,881                912
Income taxes...............................             3,346                3,881               (535)
                                             ------------------    -----------------   ----------------
  Total non-fuel operating expenses........           114,421              116,392             (1,971)
                                             ------------------    -----------------   ----------------
Operating income...........................         $  18,652            $  17,730            $   922
                                             ------------------    -----------------   ----------------

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 Generation and Marketing 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 following table shows gas revenues by customer and average customers:

                           Gas Revenues
                          (In thousands)

                                                  Year Ended
                                                 December 31,
                                              2002          2001
                                           ------------  ------------

Residential..........................         $ 172,200     $ 232,321
Commercial...........................            52,530        68,895
Industrial...........................             2,872        27,519
Transportation*......................            17,735        20,188
Other................................            26,781        36,495
                                           ------------  ------------
                                              $ 272,118     $ 385,418
                                           ============  ============
Average customers....................           443,396       434,591
                                           ============  ============

35

The following table shows gas throughput by customer class:

                          Gas Throughput
                     (Thousands of decatherms)

                                                  Year Ended
                                                 December 31,
                                              2002          2001
                                           ------------  ------------
Residential...........................           29,627        27,848
Commercial............................           12,009        10,421
Industrial............................              749         3,920
Transportation*.......................           44,889        51,395
Other.................................            4,806         4,355
                                           ------------  ------------
                                                 92,080        97,939
                                           ============  ============

*Customer-owned gas.

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 operating expenses decreased $2.0 million or 1.7%. Administrative and other costs decreased only slightly from the prior year. In 2002, the Company recognized lower bad debt expense of $3.0 million because of collection improvements and the absence of losses from the bankruptcy of a significant customer in 2001, 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. These decreases were mostly offset by higher allocated corporate administrative costs of $5.6 million. Transmission and 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. Taxes other than income taxes increased $0.9 million or 13.3% due to the absence of favorable audit outcomes by certain tax authorities recognized in 2001. Income taxes, which include income taxes for interest charges, decreased $0.5 million or 13.8% due to lower pre-tax income.

36

Generation and Marketing Operations

The table below sets forth the operating results for the Generation and Marketing business segment.

                                                    Generation and Marketing
                                                    Year Ended December 31,
                                            -----------------------------------------
                                                  2002                   2001               Variance
                                            ------------------     ------------------   -----------------
                                                                   (In thousands)
Operating revenues:
  External customers......................         $ 325,385             $1,393,635        $ (1,068,250)
  Intersegment revenues...................           348,935                341,608               7,327
                                            ------------------     ------------------   -----------------
  Total revenues..........................           674,320              1,735,243          (1,060,923)
                                            ------------------     ------------------   -----------------
Cost of energy sold.......................           406,310              1,267,887            (861,577)
Intersegment purchases....................               707                    707                   -
                                            ------------------     ------------------   -----------------
  Total cost of energy....................           407,017              1,268,594            (861,577)
                                            ------------------     ------------------   -----------------
Gross margin..............................           267,303                466,649            (199,346)
                                            ------------------     ------------------   -----------------
Administrative and other..................            35,452                 34,730                 722
Energy production costs...................           146,901                149,585              (2,684)
Depreciation and amortization.............            43,837                 42,766               1,071
Taxes other than income taxes.............            11,060                  8,865               2,195
Income taxes..............................             5,316                 80,138             (74,822)
                                            ------------------     ------------------   -----------------
  Total non-fuel operating expenses.......           242,566                316,084             (73,518)
                                            ------------------     ------------------   -----------------
Operating income..........................          $ 24,737              $ 150,565          $ (125,828)
                                            ------------------     ------------------   -----------------

Operating revenues declined $1.1 billion or 61.1% for the year to $674.3 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 $34 per MWh in 2002 versus $111 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 9.5 million MWh of electricity for the year ended December 31, 2002, compared to 12.6 million MWh for the same period in 2001.

37

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 following table shows revenues by customer class:

Generation and Marketing Revenues
(In thousands)

                                                  Year Ended
                                                 December 31,
                                             2002            2001
                                        --------------- ---------------

Intersegment sales.................          $348,935       $ 341,608
Long-term contract.................            40,132          77,250
Other merchant sales*..............           266,956       1,313,739
Other..............................            18,297           2,646
                                        --------------- ---------------
                                             $674,320      $1,735,243
                                        =============== ===============

*Includes mark-to-market gains/(losses).

The following table shows sales by customer class:

                  Generation and Marketing Sales
                         (Megawatt hours)

                                                 Year Ended
                                                December 31,
                                            2002            2001
                                       --------------- ---------------

Intersegment sales.................         7,406,506       7,255,297
Long-term contract.................           844,168       1,463,031
Other merchant sales...............         8,605,987      11,114,069
                                       --------------- ---------------
                                           16,856,661      19,832,397
                                       =============== ===============

The gross margin, or operating revenues minus cost of energy sold, decreased $199.3 million or 42.7%. 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.

38

Total non-fuel operating expenses decreased $73.5 million or 23.3%. Administrative and other costs increased $0.7 million or 2.1% for the year. This increase is primarily due to higher corporate administrative cost allocations of $4.9 million, partially offset by an adjustment of $1.6 million to prior year San Juan Generating Station ("SJGS") participant billings (the Company is the operator of SJGS and shares costs with other owners) and lower costs of $2.3 million resulting from increased capital activity for generation expansion. Energy production costs decreased $2.7 million or 1.8% for the period reflecting the benefits of $2.3 million for the acceleration into 2001 of a planned outage at SJGS, decreased costs of $3.5 million for planned outages at SJGS and an adjustment of $3.6 million to prior year Palo Verde Nuclear Generating Station ("PVNGS") billings from Arizona Public Service Company, the operator of PVNGS. These cost decreases were partially offset by costs of $4.0 million related to the future expansion of Afton Generating Station ("Afton"), severance costs of $1.6 million at PVNGS and Four Corners Power Plant ("Four Corners"), costs of $1.4 million for planned and unplanned outages at Four Corners and costs of $0.8 million at Lordsburg Generating Station ("Lordsburg"), which became fully operational in June 2002. Depreciation and amortization increased $1.1 million or 2.5% due to the addition of Lordsburg. Taxes other than income taxes increased $2.2 million or 24.8% reflecting adjustments recorded in the prior year for favorable audit outcomes by certain tax authorities. Income taxes, which include income taxes for interest charges, decreased $74.8 million or 93.4% due to a decline in pre-tax income.

Corporate

Corporate administrative and general costs, which represent costs that are driven primarily by corporate-level activities, increased $3.0 million or 3.2% for the period to $95.4 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.

Other Non-Operating

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

39

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.

(Intentionally left blank)

40

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.

Earnings in both 2001 and 2000 were affected by certain special gains and non-recurring charges. These special items are detailed in the individual business segment discussions below. The following table enumerates these special gains and non-recurring charges and shows their effect on diluted earnings per share, in thousands, except per share amounts.

                                                           2001                           2000
                                                ----------------------------  ------------------------------
                                                                   EPS                             EPS
                                                  Earnings      (Diluted)        Earnings       (Diluted)
                                                -------------- -------------  --------------- --------------
Net Earnings Available for Common
   Shareholders...............................      $149,847         $3.77         $100,360          $2.53
                                                -------------- -------------  --------------- --------------
Adjustment for Special (Gains) and Charges
  (net of income tax effects):
  Contribution to PNM Foundation..............         3,021          0.08              -               -
  Nonrecoverable coal
    mine decommissioning costs................         7,840          0.20              -               -
  Write-off of Avistar investments............         7,907          0.20              -               -
  Settlement of lawsuit.......................             -             -           (8,306)         (0.21)
  Resolution of two gas rate claims...........             -             -           (2,808)         (0.07)
  Impairment of certain regulatory assets.....             -             -            6,552           0.16
  Costs for the acquisition of long-term
    wholesale customer........................             -             -            2,740           0.07
  Western Resources acquisition costs.........        10,859          0.27            4,047           0.10
                                                -------------- -------------   -------------- --------------
    Total.....................................        29,627          0.75            2,225           0.05
                                                -------------- -------------   -------------- --------------
Earnings Available For Common
   Shareholders Excluding Special Gains
   and Charges................................      $179,474         $4.52         $102,585          $2.58
                                                ============== =============   =============  ==============

To adjust reported net earnings and diluted earnings per share to exclude the special gains and non-recurring charges, special gains, net of income tax expense, are subtracted from reported net earnings under GAAP and non-recurring charges, net of income tax benefit, are added back to reported net earnings under GAAP.

41

The following discussion is based on the financial information presented in the Consolidated Financial Statements - Segment Information note. The tables below set forth the operating results for each business segment.

Utility Operations

Electric

The table below sets forth the operating results for the Electric business segment.

Year Ended December 31, 2001

                                                        Electric
                                                 Year Ended December 31,
                                          ---------------------------------------
                                                2001                  2000               Variance
                                          -----------------      ----------------     ----------------
                                                                (In thousands)
Operating revenues:
  External customers....................         $559,226             $ 538,758             $ 20,468
  Intersegment revenues.................              707                   707                    -
                                          -----------------      ----------------     ----------------
  Total revenues........................          559,933               539,465               20,468
                                          -----------------      ----------------     ----------------
Cost of energy sold.....................            5,102                 5,048                   54
Intersegment purchases..................          341,608               324,744               16,864
                                          -----------------      ----------------     ----------------
  Total cost of energy..................          346,710               329,792               16,918
                                          -----------------      ----------------     ----------------
Gross margin............................          213,223               209,673                3,550
                                          -----------------      ----------------     ----------------
Administrative and other................           48,821                46,905                1,916
Depreciation and amortization...........           32,666                31,480                1,186
Transmission and distribution costs.....           37,376                33,092                4,284
Taxes other than income taxes...........           12,336                14,102               (1,766)
Income taxes............................           24,607                27,743               (3,136)
                                          -----------------      ----------------     ----------------
  Total non-fuel operating expenses.....          155,806               153,322                2,484
                                          -----------------      ----------------     ----------------
Operating income........................         $ 57,417              $ 56,351              $ 1,066
                                          -----------------      ----------------     ----------------

Operating revenues increased $20.5 million or 3.8% for the period to $559.9 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 period, 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 $9.6 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.

42

The following table shows electric revenues by customer class and average customers:

                         Electric Revenues
                          (In thousands)

                                                  Year Ended
                                                 December 31,
                                              2001          2000
                                           ------------  ------------
Residential..........................         $ 187,600     $ 186,133
Commercial...........................           242,372       238,243
Industrial...........................            82,752        79,671
Other................................            47,209        35,418
                                           ------------  ------------
                                              $ 559,933     $ 539,465
                                           ============  ============
Average customers....................           377,589       368,506
                                           ============  ============

The following table shows electric sales by customer class:

                          Electric Sales
                         (Megawatt hours)

                                                  Year Ended
                                                 December 31,
                                              2001          2000
                                           ------------  ------------
Residential..........................         2,197,889     2,171,945
Commercial...........................         3,213,208     3,133,996
Industrial...........................         1,603,266     1,544,367
Other................................           240,934       238,635
                                           ------------  ------------
                                              7,255,297     7,088,943
                                           ============  ============

The gross margin, or operating revenues minus cost of energy sold, increased $3.6 million, which reflects the increased energy sales, transmission revenue and property leasing revenue, partially offset by higher cost for the electricity sold to retail customers. Electric exclusively purchases power from Generation and Marketing at Company developed prices which are not based on market rates. These intercompany revenues and expenses are eliminated in the consolidated results.

Total non-fuel operating expenses increased $2.5 million or 1.6%. Administrative and general costs increased $1.9 million or 4.1% for the period. This increase is primarily due to higher allocated corporate administrative costs of $5.0 million. Consulting expenses focused on cost control and process improvement initiatives also contributed to the increase. These increases were

43

partially offset by lower bad debt and collection expense of $3.4 million. 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. Depreciation and amortization increased $1.2 million or 3.8% due to a higher depreciable plant base. Transmission and distribution costs increased $4.3 million or 12.9% primarily due to a non-recurring increase in maintenance to improve reliability for the transmission and distribution systems. Taxes other than income taxes decreased $1.8 million or 12.5% reflecting favorable audit outcomes by certain tax authorities and tax planning strategies in 2001. Income taxes, which include taxes associated with interest charges, decreased $3.1 million or 11.3% due to lower pre-tax income.

Gas

The table below sets forth the operating results for the Gas business segment.

                                                  Year Ended December 31,
                                            -------------------------------------
                                                 2001                 2000             Variance
                                            ---------------      ----------------    --------------
                                                                (In thousands)
Operating revenues........................      $ 385,418             $ 319,924          $ 65,494
Total cost of energy......................        251,296               195,334            55,962
                                            ---------------      ----------------    --------------
Gross margin..............................        134,122               124,590             9,532
                                            ---------------      ----------------    --------------
Administrative and other..................         53,093                44,104             8,989
Depreciation and amortization.............         21,465                19,994             1,471
Transmission and distribution costs.......         31,072                27,206             3,866
Taxes other than income taxes.............          6,881                 8,502            (1,621)
Income taxes..............................          3,881                 5,680            (1,799)
                                            ---------------      ----------------    --------------
  Total non-fuel operating expenses.......        116,392               105,486            10,906
                                            ---------------      ----------------    --------------
Operating income..........................       $ 17,730             $  19,104          $ (1,374)
                                            ---------------      ----------------    --------------

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 the Company's Generation and Marketing Operations.

(Intentionally left blank)

44

The following table shows gas revenues by customer and average customers:

                           Gas Revenues
                          (In thousands)

                                                  Year Ended
                                                 December 31,
                                              2001          2000
                                           ------------  ------------
Residential..........................         $ 232,321     $ 191,231
Commercial...........................            68,895        52,964
Industrial...........................            27,519        24,206
Transportation*......................            20,188        14,163
Other................................            36,495        37,360
                                           ------------  ------------
                                              $ 385,418     $ 319,924
                                           ============  ============
Average customers....................           434,591       434,943
                                           ============  ============

The following table shows gas throughput by customer class:

                          Gas Throughput
                     (Thousands of decatherms)

                                                  Year Ended
                                                 December 31,
                                              2001          2000
                                           ------------  ------------
Residential...........................           27,848        28,810
Commercial............................           10,421         9,859
Industrial............................            3,920         5,038
Transportation*.......................           51,395        44,871
Other.................................            4,355         6,426
                                           ------------  ------------
                                                 97,939        95,004
                                           ============  ============

*Customer-owned gas.

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 operating expenses increased $10.9 million or 10.3%. Administrative and general costs increased $9.0 million or 20.4%. This increase is due to higher allocated corporate administrative costs of $6.3 million and consulting expenses incurred in connection with cost control and process improvement initiatives, partially offset by decreased bad debt and collection costs of $1.8 million. Depreciation and amortization increased $1.5 million or 7.4% for the period due to a higher depreciable plant base. Transmission and 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

45

improving reliability and effectiveness of its retail distribution system. Taxes other than income taxes decreased $1.6 million or 19.1% due to favorable audit outcomes by certain tax authorities. Income taxes, which include taxes for interest charges, decreased $1.8 million or 31.7% due to lower pre-tax income.

Generation and Marketing Operations

The table below sets forth the operating results for the Generation and Marketing business segment.

                                                  Year Ended December 31,
                                            ------------------------------------
                                                 2001                 2000             Variance
                                            ----------------      --------------    ----------------
                                                                (In thousands)
Operating revenues:
  External customers......................     $ 1,393,635           $ 750,434           $ 643,201
  Intersegment revenues...................         341,608             324,744              16,864
                                            ----------------      --------------    ----------------
  Total revenues..........................       1,735,243           1,075,178             660,065
                                            ----------------      --------------    ----------------
Cost of energy sold.......................       1,267,887             749,499             518,388
Intersegment purchases....................             707                 707                   -
                                            ----------------      --------------    ----------------
  Total cost of energy....................       1,268,594             750,206             518,388
                                            ----------------      --------------    ----------------
Gross margin..............................         466,649             324,972             141,677
                                            ----------------      --------------    ----------------
Administrative and other..................          34,730              32,886               1,844
Energy production costs...................         149,585             137,202              12,383
Depreciation and amortization.............          42,766              41,559               1,207
Taxes other than income taxes.............           8,865              11,457              (2,592)
Income taxes..............................          80,138              23,417              56,721
                                            ----------------      --------------    ----------------
  Total non-fuel operating expenses.......         316,084             246,521              69,563
                                            ----------------      --------------    ----------------
Operating income..........................       $ 150,565            $ 78,451            $ 72,114
                                            ----------------      --------------    ----------------

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 $660.1 million or 61.4% for the period to $1.7 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 12.6 million MWh of electricity in 2002, compared to 12.4 million MWh in the prior period. The average price realized by the Company increased to approximately $111 per MWh in 2001 compared to $61 per MWh in 2000. Wholesale revenues from third-party customers increased from $750.4 million to $1.4 billion, an 85.7% increase.

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The following table shows revenues by customer class:

Generation and Marketing Revenues
(In thousands)

                                                 Year Ended
                                                December 31,
                                            2001             2000
                                       ---------------- ---------------

Intersegment sales.................         $ 341,608       $ 324,744
Long-term contract.................            77,250          87,731
Other merchant sales*..............         1,313,739         655,881
Other..............................             2,646           6,822
                                       ---------------- ---------------
                                           $1,735,243      $1,075,178
                                       ================ ===============

*Includes mark-to-market gains/(losses).

The following table shows sales by customer class:

                  Generation and Marketing Sales
                         (Megawatt hours)

                                                  Year Ended
                                                 December 31,
                                             2001             2000
                                        ---------------- ---------------

Intersegment sales...................         7,255,297       7,088,943
Long-term contract...................         1,463,031         330,003
Other merchant sales.................        11,114,069      12,022,125
                                        ---------------- ---------------
                                             19,832,397      19,441,071
                                        ================ ===============

The gross margin, or operating revenues minus cost of energy sold, increased $141.7 million or 43.6%. 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.

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Total non-fuel operating expenses increased $69.6 million or 28.2%. Administrative and general costs increased $1.8 million or 5.6% for the period. This increase is primarily due to higher allocated corporate administrative costs of $5.4 million and higher power marketing expenses of $1.0 million mainly for additional incentive bonuses and consulting fees and other expenses of $0.6 million related to business development and process improvement. This increase was partially offset by lower year-over-year Generation and Marketing business development costs of $4.5 million due to significant costs related to the acquisition of a long-term wholesale customer. Energy production costs increased $12.4 million or 9.0% for the year. The increase is primarily due to higher maintenance costs of $7.9 million in 2001 resulting from scheduled and unscheduled outages at PVNGS, SJGS and Reeves Generating Station ("Reeves"), additional incentive bonuses of $0.5 million at SJGS, and increased operations costs of $1.2 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 $1.3 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 $2.3 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. Depreciation and amortization increased $1.2 million or 2.9% for the period due to a higher depreciable plant base. Taxes other than income taxes decreased $2.6 million or 22.6% as a result of favorable audit outcomes by certain tax authorities. Income taxes, which include taxes for interest charges, increased $56.7 million or 242.2% due to an increase in pre-tax income.

Unregulated Businesses

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 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.

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Corporate

Corporate administrative and general costs, which represent costs that are driven exclusively by corporate-level activities, increased $13.3 million or 16.8% for the period to $92.4 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.

Other Non-Operating Costs

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 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.

FUTURE EXPECTATIONS

On January 2, 2003, the Company announced that it expects 2003 earnings for the twelve months to be in the range of $1.80 to $2.05. Although the Company's electric utility continues to perform well, the depressed level of wholesale prices in the West, coupled with the significantly decreased marketing activity in that market, has severely limited the earnings potential of Generation and Marketing. This estimated range is based on a number of factors, including growth rates in the New Mexico service territory, wholesale prices, merchant sales velocity (ability to market around assets) and spark spread.

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Please note that the following are simplifying guidelines that attempt to quantify a number of complex and interdependent factors affecting the Company's earnings. These are provided to generally assist investors in developing their own independent assessment of the Company's future earnings prospects.

As a result of an agreement ("Global Electric Agreement") approved by regulators in January 2003, retail electric rates will decline by 4% beginning in September 2003, which is projected to reduce earnings by $0.08 per share for the year. The Global Electric Agreement also provides for recovery of $100 million of coal mine decommissioning costs to be amortized over 17 years. Those costs will be amortized beginning September 2003, reducing earnings by $0.03 per share in 2003. Retail electric revenue growth is projected at about 2%, with every 1% increase in load adding $0.05 per share. For further information see "Other Issues Facing the Company - Merchant Plant Filing and Global Electric Agreement."

Return on the Company's gas assets will continue to be poor in 2003. In 2002, this return was below 3%, and in 2003 returns will be reduced by another $3 million through the expiration of an existing rate rider in January 2003. The Company filed a gas rate case in January 2003, seeking a $37.6 million rate increase in cost of service rates and a $1.6 million increase in miscellaneous fees. This case is subject to a ten-month timeframe, which may be extended. If an order is received within this timeframe, the Company would have some small improvement in earnings per share in December 2003.

On the wholesale side, the baseline forecast assumes continued low liquidity and a marginal improvement in prices. The Company is projecting an average market price of about $34/MWh, around-the-clock on an annualized basis. Although the current forward prices are stronger than this, the forward price curve cannot translate directly to the Company's mix of short-term and long-term sales. A $1 change in market price equals $0.05 per share. The Company is assuming a merchant sales velocity for the year of about 1.5, which is about 50% more power sold than actually generated by PNM. Velocity did pick up at the end of 2002, boosting overall velocity for the year to 1.6. When velocity goes from 1.5 to 1.6, earnings increase $0.01 per share. The Company's 2003 earnings guidance assumes spark spread remains at levels that will restrict operation of PNM's gas fired assets to capacity factors below 10%.

Several increases in cost affect earnings potential in 2003. The Company's earnings assumptions include increased medical and pension costs for the year. The impact of low interest rates and poor market performance on the pension fund in 2002 will be offset somewhat by a $20 million contribution to the fund in 2003. Insurance costs since September 11, 2001 have also risen sharply.

Longer plant maintenance schedules and lost market opportunity from plant unavailability will also put pressure on earnings in 2003. PVNGS will replace a steam generator in Unit 2, which will add forty-two days to its regular planned outage schedule. San Juan has scheduled two major outages this year, extending the regular outage schedule by fifty days more than 2002. In addition, this will be the first full year of operation and maintenance costs and depreciation for the Company's new plants in southern New Mexico, Afton and Lordsburg.

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In 2002, the Company's construction expenditures were $240 million of which, $67.0 million was for new generating plants. Over the five-year planning horizon, the Company expects capital expenditures, not inclusive of any generation acquisitions, to average $140 million a year. In 2003, capital expenditures are estimated to be $156 million due to the front loading of certain projects such as the replacement of the steam generator at PVNGS, increased plant outage schedules including a turbine rewind at San Juan, a turbine progress payment and other non-utility capital increases. The Company expects to fund these expenditures from internal cash generation and current debt capacity.

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 remains low, 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.

This discussion of future expectations is forward looking information within the meaning of Section 21E of the Securities Exchange Act of 1934. The achievement of expected results is dependent upon the assumptions described in the preceding discussion, and is qualified in its entirety by the Private Securities Litigation Reform Act of 1995 disclosure - (see "Disclosure Regarding Forward Looking Statements" below) - and the factors described within the disclosure that could cause the Company's actual financial results to differ materially from the expected results discussed above.

CRITICAL ACCOUNTING POLICIES AND ESTIMATES

The preparation of financial statements in accordance with GAAP requires that management to select and apply accounting policies that best provide the framework to report the Company's results of operations and financial position. The selection and application of those policies require management to make difficult subjective or complex judgments concerning reported amounts of revenue and expenses during the reporting period and the reported amounts of assets and liabilities at the date of the financial statements. The judgments and uncertainties inherent in this process affect the application of those policies. As a result, there exists the likelihood that materially different amounts would be reported under different conditions or using different assumptions. Management has identified the following accounting policies that it deems critical to the portrayal of the Company's financial condition and results and that involve significant subjectivity. Management believes that its selection and application of these policies best represent the operating results and financial position of the Company. The following discussion provides information on the processes utilized by management in making judgments and assumptions as they apply to its critical accounting policies.

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Revenue Recognition

Unbilled Utility Revenues

Revenues related to the sale of energy are generally recorded when service is rendered or energy is delivered to customers. 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. This unbilled 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 Purchase Gas Adjustment Clause ("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.

Unbilled Wholesale Power Marketing Revenues

Wholesale power marketing revenues are recognized in the month the energy is delivered to the customer and are based on the actual amounts supplied to the customer. 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.

Accrued unbilled utility revenues and unbilled wholesale power marketing revenues are combined and specifically identified in the consolidated balance sheets.

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Regulatory Assets and Liabilities

The accounting rules for rate-regulated entities require a company to reflect the effects of regulatory decisions in its financial statements pursuant to Statement of Financial Accounting Standards, No. 71, "Accounting for the Effects of Certain Types of Regulation" ("SFAS 71"). In accordance with these accounting rules, the Company has deferred certain costs that are rate recoverable and recorded certain liabilities for amounts to be returned to retail customers pursuant to the rate actions of the PRC and its predecessor and the Federal Energy Regulatory Commission ("FERC"). Substantially all of the Company's regulatory assets and regulatory liabilities are reflected in rates charged to retail customers or have been addressed in a regulatory proceeding. To the extent that management concludes that the recovery of a regulatory asset is no longer probable due to changes in 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 continually assesses whether the regulatory assets are probable of future recovery by considering factors such as applicable regulatory environment changes, recent rate orders to other regulated entities in the same jurisdiction, anticipated future regulatory decisions and their impact, competition on the ratemaking process and the ability to recover costs, and the status of any deregulation legislation.

The Company discontinued the application of regulatory accounting as of December 31, 1999, for the generation portion of its business effective with the passage in New Mexico of the Electric Utility Industry Restructuring Act of 1999 ("Restructuring Act"). The Company evaluated these assets under the same impairment rules that it uses to evaluate tangible long-lived assets. During 2000, the Company entered into negotiations with the PRC staff and other interveners regarding a rate settlement in anticipation of open access occurring in New Mexico under the Restructuring Act. As part of the negotiations, the parties in the settlement discussions agreed on a fixed dollar amount of stranded costs that would be recovered through a non-bypassable wires charge. In 2000, the Company recorded a charge to earnings of $6.6 million as valuation allowances against certain income tax related regulatory assets. This charge was equal to the difference between the agreed to dollar amount and the actual stranded costs that were recorded on the Company's balance sheet. The write-off was not specific to any one particular regulatory asset but was simply the difference between the two previously discussed amounts. Before a final settlement was reached, the New Mexico Legislature in 2001 passed Senate Bill 266, that delayed open access. With the passage of Senate Bill 266, the settlement discussions terminated. Therefore, in 2001 the Company reversed the 2000 valuation allowance as it was determined that it was no longer required due to changes in the evaluation of the Company's regulatory strategy in light of the holding company filing in May 2001.

In August 2001, the Company signed an agreement with San Juan Coal Company ("SJCC") and Tucson Electric Power Company ("Tucson") to replace two surface mining operations with a single underground mine located adjacent to the SJGS. As a result of the negotiations for the new coal contract, the Company recorded a regulatory asset in 1999 for the estimated costs anticipated to close the surface mining operation. This regulatory asset was anticipated to be recovered through the non-bypassable wires charge discussed above. As the settlement discussions progressed, it became clear that a portion of the costs capitalized by the Company for decommissioning the coal mine would not be collectible. As a result, the Company was unable to defer this portion of coal mine decommissioning costs as a regulatory asset for future recovery through regulated rates. Therefore, in 2001, the Company wrote-off $13 million for the portion of coal mine decommissioning costs associated with the Company's FERC firm requirements customers and a portion of SJGS Unit 4. In addition, the Company wrote-off $11.1 million of additional regulatory assets of which $8.1 million related to non-recoverable transition costs and $3 million for other non-recoverable regulatory assets.

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On October 10, 2002, the Company and several other parties signed the Global Electric Agreement, that provides for a five-year rate path for the Company's New Mexico jurisdictional customers beginning in September of 2003. The Global Electric Agreement also seeks to repeal the Restructuring Act. The Company will re-apply SFAS 71 to its Generation and Marketing Operations during the first quarter of 2003 as the Global Electric Agreement was approved by the PRC on January 28, 2003. In connection with the Global Electric Agreement, the Company has agreed to forego recovery of the transition costs incurred to date. The forgone 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 communication costs. The Company will incur a one-time charge of $16.7 million for the non-recoverable transition costs in the first quarter of 2003. As the Company's electric rates are fixed, the opportunity to recover increased costs and the costs of new investment in facilities through rates during the five-year rate freeze period is also limited. The Company will continue to assess the recoverability of its regulatory assets. If future recovery of costs ceases to be probable, the Company would be required to record a charge for the portion of the costs that were not recoverable in current period earnings.

Asset Impairment

The Company evaluates its tangible long-lived assets for impairment whenever indicators of impairment exist pursuant to 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"). These potential impairment triggers would include fluctuating market conditions as a result of industry deregulation; planned and scheduled customer purchase commitments; future market penetration; customer growth; fluctuating market prices (resulting from changing fuel costs, other economic conditions, etc.); weather patterns, and other market trends. Accounting rules require that if the sum of the undiscounted expected future cash flows from a company's asset (without interest charges that will be recognized as expenses when incurred), is less than the carrying value of the asset, an asset impairment must be recognized in the financial statements. The amount of impairment recognized is calculated by subtracting the fair value of the asset from the carrying value of the asset.

Impairment testing for the Company's power generation assets is done in two parts: those power generation assets used to supply New Mexico retail customer needs (evaluated as one group) and those used to supply wholesale market needs (evaluated as another group). Management's assumptions about future prices, volumes, and other market trends in the wholesale electricity market have fluctuated in the past and are expected to continue to be volatile. A significant adverse change in these assumptions may result in an impairment of the Company's power generation assets. Please note that the assumptions inherent in the Company's analysis of asset impairment are inter-dependent. Changes in any one assumption is a simplified view which attempts to give the reader an understanding of the sensitivities affecting the Company's earnings. If market prices were to decrease 22% below the Company's projected average market price of $34/MWh, the Company may be required to recognize a charge to earnings for the related asset impairment in accordance with SFAS 144.

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Pension and Other Post-retirement Benefits

The Company and its subsidiaries maintain a qualified defined benefit pension plan (the "Plan"), which covers eligible non-union and union employees including officers. The Plan was frozen at the end of 1997 to new participants, salary levels and benefits. The Company's policy is to fund actuarially-determined contributions.

The Company's income for its Plan approximated $1.4 million for the year ended December 31, 2002, and is calculated based upon a number of actuarial assumptions, including an expected long-term rate of return on the Plan assets of 9.0%. In developing the expected long-term rate of return assumption, the Company evaluated input from its actuaries, including their review of asset class return expectations as well as long-term inflation assumptions. This long-term rate of return assumption compares to the historical 10-year compounded return of 8.6% through the end of December 2002. The expected long-term rate of return on the Plan assets is based on an asset allocation assumption of 65% with equity managers, 25% with fixed income managers, and 10% with alternative investments that are primarily real estate and timber. Because of market fluctuation, the Plan's actual asset allocation as of December 31, 2002 was 63% with equity managers, 27% with fixed income managers, and 10% with alternative investments. The Company reviews the actual asset allocation and periodically rebalances the asset allocation to the targeted allocation. The Company continues to believe that 9.0% is a reasonable long-term rate of return on the Plan's assets, despite the recent market downturn in which the Plan assets had an actual loss of 8.3% for the twelve months ended December 31, 2002. The Company will continue to evaluate its actuarial assumptions, including expected rate of return, at least annually, and will adjust as necessary.

The Company bases its determination of pension expense or income on a market-related valuation of assets, which reduces year-to-year volatility. If investment return is outside a range of 5% to 13% (expected long-term rate of return plus or minus 4%), this market-related valuation recognizes the portion of return that is outside the range over a five year period from the year in which the return occurs. Since the market-related value of assets recognizes the portion of return that is outside the range over a five-year period, the future value of assets will be impacted as previously deferred returns are recorded.

The discount rate that the Company utilizes for determining future pension obligations is based on a review of long-term high-grade bonds. The discount rate determined on this basis has decreased to 6.75% at September 30, 2002 from 7.50% at September 30, 2001. Based on an expected rate of return on the Plan assets of 9.0%, a discount rate of 6.75% and various other assumptions, it is estimated that the pension expense for the Plan will approximate $3.2 million in fiscal year 2003 and $3.8 million in fiscal year 2004. Future actual pension income or expense will depend on future investment performance, changes in future discount rates and various other factors related to the populations participating in our pension plans.

Lowering the Plan's expected long-term rate of return on pension assets by 0.5% (from 9% to 8.5%) would have lowered pension income for fiscal 2002 by approximately $1.9 million. Lowering the discount rate by 0.5% would have lowered pension income for fiscal year 2002 by approximately $200,000.

55

The value of the Plan assets has decreased from $339.7 million at September 30, 2001 to $325.1 million at September 30, 2002 including $26.1 million of contributions during 2002. The Company expects to make $20 million in contributions for the 2003 plan year. These contributions are expected to help the Company avoid potential actions of the Pension Benefit Guaranty Corporation for under-funded plans including higher insurance premiums and notification to participants of the under-funded plan status.

Decommissioning Costs

Accounting for decommissioning costs for nuclear and fossil-fuel generation involves significant estimates related to costs to be incurred many years in the future. Changes in these estimates could significantly impact the Company's financial position, results of operation and cash flows. The Company owns and leases nuclear and fossil-fuel facilities that are within and outside of its retail service areas. The Company will adopt the new accounting requirements of Statement of Financial Accounting Standards No. 143, "Accounting for Asset Retirement Obligations" ("SFAS 143") in the first quarter of 2003. Under SFAS 143, the Company is only required to recognize and measure decommissioning liabilities for tangible long-lived assets for which a legal obligation exists. Adoption of the statement will change the Company's method of accounting for both nuclear generation decommissioning and fossil-fuel generation decommissioning. See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - New and Proposed Accounting Standards", for additional discussion regarding the Company's accounting policy for decommissioning and the anticipated effects for adoption of the new standard. Nuclear decommissioning costs are based on site-specific estimates of the costs for removing all radioactive and other structures at the site. PVNGS Unit 3 is currently excluded from the Company's retail rate base while Units 1 and 2 are included in the Company's retail rate base. The Company collects a provision for ultimate decommissioning of Units 1 and 2 in its rates. Fossil-fuel decommissioning costs are also approved by the PRC as a component of the Company's depreciation rates. The Company believes that it will continue to be able to collect for its legal asset retirement obligations for nuclear and fossil-fuel generation activities included in the ratemaking process described above.

In addition, the Company has a contractual obligation with the PVNGS participants to fund separately the nuclear decommissioning at a level in excess of what the Company has identified as its legal asset retirement obligation under SFAS 143. The contractual funding obligation is based on a site-specific estimate prepared by a third party. The Company's most recent site-specific estimates for nuclear decommissioning costs were developed in 2001, using 2001 cost factors, and are based on prompt dismantlement decommissioning, reflecting the costs of removal discussed above, with such removal occurring shortly after operating license expiration. The Company's share of the contractual funding obligation is approximately $201 million (2001 dollars) at December 31, 2002. The estimates are subject to change based on a variety of factors including, cost escalation, changes in technology applicable to nuclear decommissioning and changes in federal, state or local regulations. The operating licenses for PVNGS Units 1, 2 and 3 expire in 2024, 2025, and 2027, respectively. The Company does not have a similar contractual funding obligation related to its fossil-fuel plants.

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Self-Insurance

The Company self-insures for certain losses related to general liability, workers' compensation and automobile claims. The Company maintains insurance with third-party insurers in excess of the Company's self-insured retentions to limit the Company's exposure per occurrence or accident, as applicable. The Company's self-insurance liabilities reflect the estimated ultimate cost of claims incurred as of the balance sheet date. The estimated liabilities are not discounted and are established based upon claims filed, estimated claims incurred but not reported, and analyses of industry and historical data. Management reviews the amounts recorded for these liabilities on a quarterly basis to ensure that they are appropriate. While management believes that these estimates are reasonable based on the information available, the Company's financial results could be impacted if actual trends, including the severity or frequency of claims or fluctuations in premiums, differ from the Company's estimates.

Contingent Liabilities

There are various claims and lawsuits pending against the Company and certain of its subsidiaries. The Company has recorded a liability where the effect of litigation can be estimated and where an outcome is considered probable. Management's estimates are based on its knowledge of the relevant facts at the time of the issuance of the Company's consolidated financial statements. Subsequent developments could materially alter management's assessment of a matter's probable outcome and the estimate of liability.

Environmental Issues

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, current laws and regulations, experience gained at similar sites, and the probable level of involvement and financial condition of other potentially responsible parties. These estimates include costs for site investigations, remediation, operations and maintenance, monitoring and site closure. Unless there is a probable amount, the Company records the lower end of this reasonably likely range of costs (classified as other long-term liabilities at undiscounted amounts). Subsequent developments could materially alter management's assessment of a matter's probable outcome and the estimate of liability.

Legal Fees

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 Statement of Financial Accounting Standards No. 5 "Accounting for Contingencies" ("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 and professional fees.

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See "Item 7A. Quantitative and Qualitative Disclosure About Market Risk - Interest Rate Risk and Financial Instruments" for discussion regarding the Company's accounting policies and sensitivity analysis for the Company's financial instruments and derivative energy and other derivative contracts. See also "Planned Financing Activities" below for additional discussion regarding the Company's accounting policies for forward interest swaps.

LIQUIDITY AND CAPITAL RESOURCES

At December 31, 2002, the Company had cash and short-term cash investments of $83.3 million compared to $179.2 million in cash and short-term and long-term cash investments at December 31, 2001. Certain long-term investments have been reclassified as short-term to reflect the Company's liquidity needs to fund certain construction projects in 2002.

Cash provided from operating activities for the year ended December 31, 2002 was $97.3 million compared to cash provided by operating activities of $327.3 million for the year ended December 31, 2001. This decrease was primarily the result of a decline in operating income due to the deterioration of wholesale market conditions. Also, contributing to the decrease was a payment of $36.0 million for the termination of the surface coal mine contract, the Company's $26.1 million contribution to its pension and post-retirement benefit plans and a payment of $23.2 million to secure a long-term wholesale contract. In addition, the Company did not make its first quarter 2001 estimated federal income tax payment of $32.0 million until January 2002 because of an extension granted by the IRS to taxpayers in several counties in New Mexico as a result of wildfires in 2000. These non-recurring payments reduced operating cash flows below historical levels.

Cash used for investing activities was $200.4 million in 2002 compared to $407.0 million in 2001. Cash used for investing activities includes construction expenditures for new generating plants of $67.4 million in 2002 compared to $70.9 million in 2001. Payments for combustion turbines not yet included in plant were $31.3 million in 2002 compared to $32.6 million in 2001. In addition, cash used for investing in 2001 includes the purchase of short-term and long-term investments of $150.0 million. The change in cash used for investing activities was partially offset by the redemption of short-term investments of $76.6 million in 2002. Expenditures in 2001 reflect the acquisition of certain transmission assets and other related investing activities of $13.9 million.

Cash generated by financing activities was $78.5 million in 2002 compared to $0.4 million in 2001. Financing activities in 2002 were primarily short-term borrowings of $115.0 million compared to $35.0 million in 2001 for liquidity reasons, partially offset by an 8% increase in cash payments for common stock dividends.

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Capital Requirements

Total capital requirements include construction expenditures as well as other major capital requirements and cash dividend requirements for both common and preferred stock. The main focus of the Company's current construction program is upgrading generation systems upgrading and expanding the electric and gas transmission and distribution systems, and purchasing nuclear fuel. To preserve a strong financial position, the Company announced in 2002 its plans to eliminate capital expenditures for previously planned generation expansion until market conditions warrant further investment. Projections for total capital requirements for 2003 are $176 million and projections for construction expenditures for 2003 are $156 million including remaining payments on the combustion turbines discussed below. For 2003-2007 projections, total capital requirements are $800 million and construction expenditures are $708 million. These estimates are under continuing review and subject to on-going adjustment.

PNM had previously committed to purchase five combustion turbines for a total cost of $151.3 million. The turbines are for 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 $225 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 turbine, 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 merchant sales. These plants were not originally planned 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.

In 2002, the Company utilized cash generated from operations, cash on hand, as well as its liquidity arrangements to cover its construction commitments. The Company anticipates that internal cash generation and current debt capacity will be sufficient to meet all its capital requirements for the years 2003 through 2007. To cover the difference in the amounts and timing of cash generation and cash requirements, the Company intends to use short-term borrowings under its current and future liquidity arrangements.

Liquidity

As of February 28, 2003, PNM had $215 million of liquidity arrangements in addition to $76 million of cash. The liquidity arrangements consist of $195 million from an unsecured revolving credit facility ("Credit Facility") and $20 million in local lines of credit. PNM entered into a new revolving credit facility on December 19, 2002, which increased borrowing capacity from $150 million to $195 million. This facility will mature December 18, 2003. There were $170 million in borrowings against the Credit Facility as of February 28, 2003. In addition, the Holding Company has $15 million in local lines of credit.

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The Company's ability, if required, to access the capital markets at a reasonable cost and to provide for other capital needs is largely dependent upon its ability to earn a fair return on equity, results of operations, credit ratings, regulatory approvals and financial and wholesale market conditions. Financing flexibility is enhanced by providing a high percentage of total capital requirements from internal sources and having the ability, if necessary, to issue long-term securities, and to obtain short-term credit.

PNM's credit outlook is considered stable by Moody's Investor Services, Inc. ("Moody's") and Standard and Poor's Ratings Services ("S&P") and positive by Fitch, Inc. ("Fitch"). The Company is committed to maintaining or improving its investment grade ratings. S&P currently rates PNM's senior unsecured notes ("SUNs") and its Eastern Interconnection Project ("EIP") senior secured debt "BBB-" and its preferred stock "BB". Moody's rates PNM's SUNs and senior unsecured pollution control revenue bonds "Baa3" and preferred stock "Ba1". The EIP senior secured debt is also rated "Ba1". Fitch rates PNM's SUNs and senior unsecured pollution control revenue bonds "BBB-," PNM's EIP lease obligation "BB+" and PNM's preferred stock "BB-." Investors are cautioned that a security rating is not a recommendation to buy, sell or hold securities, that it may be subject to revision or withdrawal at any time by the assigning rating organization, and that each rating should be evaluated independently of any other rating.

Long-term Obligations and Commitments

The following tables show the Company's long-term obligations and commitments as of December 31, 2002.

                                                                Payments Due
                                    ----------------------------------------------------------------------
                                                               (In thousands)

                                                    Less than                                    After
        Contractual Obligations        Total         1 year       2-3 years     4-5 years       5 years
----------------------------------  -------------  ------------  ------------  -------------  ------------
Short-Term Debt (a)...............     $ 150,000      $150,000      $      -       $      -    $        -
Long-Term Debt....................       980,092         1,852       272,728          5,260       700,252
Operating Leases..................       446,973        28,216        58,216         62,391       298,150
Purchased Power Agreement........        213,191        23,889        48,217         34,704       106,381
Coal Contract (b).................     1,496,838       106,048       205,229        183,252     1,002,309
                                    -------------  ------------  ------------  -------------  ------------
Total Contractual Cash
   Obligations....................    $3,287,094      $310,005      $584,390       $285,607    $2,107,092
                                    =============  ============  ============  =============  ============

(a) Represents the actual outstanding balance of the Credit Facility as of December 31, 2002.
(b) Assumes deliveries under the Coal Contract. If no deliveries are made, certain minimum payments may be required under the Coal Contract.

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                                                 Amount of Commitment Expiration Per Period
                                 -----------------------------------------------------------------------
                                                             (In thousands)

                                     Total
          Other Commercial          Amounts                                                   After
             Commitments           Committed       1 year       2-3 years     4-5 years       5 years
-------------------------------  --------------  ------------  ------------  ------------  -------------

Short-Term Debt (c)............       $ 41,500      $ 41,500         $   -         $   -          $   -
Local Lines of Credit..........         35,000        35,000             -             -              -
Letters of Credit..............          5,700         5,700             -             -              -
                                 --------------  ------------  ------------  ------------  -------------
Total Commercial
   Commitments.................       $ 82,200      $ 82,200         $   -         $   -          $   -
                                 ==============  ============  ============  ============  =============

(c) Represents the unused borrowing capacity of the Credit Facility less outstanding letters of credit of $3.5 million as of December 31, 2002.

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. 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, which were loaned to Capital Trust. Capital Trust then acquired and now 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 million for the year ended December 31, 2002. The table above reflects the net lease payment.

PNM's other significant operating lease obligations include the EIP, a leased interest in transmission line with annual lease payments of $2.8 million (see "Planned Financing Activities" below), and an operating lease for the entire output of Delta, a gas fired generating plant in Albuquerque, New Mexico, with imputed annual lease payments of $6.0 million.

The Company's off-balance sheet obligations are limited to PNM's operating leases and certain financial instruments related to the purchase and sale of energy (see below). The present value of PNM's operating lease obligations for PVNGS Units 1 and 2, EIP and the Delta operating lease was $196 million as of December 31, 2002.

PNM has entered into various long-term power purchase agreements ("PPAs") obligating it to buy electricity for aggregate fixed payments of $213.2 million plus the cost of production and a return. These contracts expire December 2006 through July 2010. In addition, PNM is obligated to sell electricity for $185.2 million in fixed payments plus the cost of production and a return. These contracts expire December 2003 through June 2010. PNM's marketing portfolio as of December 31, 2002 included open contract positions to buy $59.7 million of electricity and to sell $56.1 million of electricity. In addition, PNM had open forward positions classified as normal sales of electricity under the derivative accounting rules of $140.7 million and normal purchases of electricity of $98.9 million.

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PNM 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 PNM recovers 100% of its cost of gas.

Contingent Provisions of Certain Obligations

The Holding Company and PNM have a number of debt obligations and other contractual commitments that contain contingent provisions. Some of these, if triggered, could affect the liquidity of the Company. The Holding Company or PNM could be required to provide security, immediately pay outstanding obligations or be prevented from drawing on unused capacity under certain credit agreements if the contingent requirements were to be triggered. The most significant consequences resulting from these contingent requirements are detailed in the discussion below.

PNM's master purchase agreement for the procurement of gas for its retail customers contains a contingent requirement that could require PNM to provide security for its gas purchase obligations if the seller were to reasonably believe that PNM was unable to fulfill its payment obligations under the agreement.

The master agreement for the sale of electricity in the Western Systems Power Pool ("WSPP") contains a contingent requirement that could require PNM to provide security if its debt were to fall below investment grade rating. The WSPP agreement also contains a contingent requirement, commonly called a material adverse change ("MAC") provision, which could require PNM to provide security if a material adverse change in its financial condition or operations were to occur.

PNM's committed Credit Facility contains a "ratings trigger." If PNM is downgraded or upgraded by the ratings agencies, the result would be an increase or decrease in interest cost, respectively. PNM's committed Credit Facility contains a MAC provision which, if triggered, could prevent PNM from drawing on its unused capacity under the Credit Facility. In addition, the Credit Facility contains a contingent requirement that requires PNM to maintain a debt-to-capital ratio, inclusive of off-balance sheet debt, of less than 65% as well as maintenance of an earnings before interest, taxes, depreciation and amortization ("EBITDA")/interest coverage ratio of three times. If PNM's debt-to-capital ratio, inclusive of off-balance sheet debt, were to exceed 65% or its interest coverage ratio falls below 3.0, PNM could be required to repay all borrowings under the Credit Facility, be prevented from drawing on the unused capacity under the Credit Facility, and be required to provide security for all outstanding letters of credit issued under the Credit Facility. At December 31, 2002, PNM had $5.7 million of letters of credit outstanding. The outstanding balance of the Credit Facility at December 31, 2002 was $150.0 million.

If a contingent requirement were to be triggered under the Credit Facility resulting in an acceleration of the outstanding loans under the Credit Facility, a cross-default provision in the PVNGS leases could occur if the accelerated amount is not paid. If a cross-default provision is triggered, the lessors have the ability to accelerate their rights under the leases, including acceleration of all future lease payments.

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Planned Financing Activities

As of December 31, 2002, PNM has $268.4 million of long-term debt that matures in August 2005 excluding sinking fund payments related to EIP secured lease bonds. All other long-term debt of PNM matures in 2016 or later. The Company could enter into other long-term financings for the purpose of strengthening its balance sheet, funding growth and reducing its cost of capital. The Company continues to evaluate its investment and debt retirement options to optimize its financing strategy and earnings potential. No additional first mortgage bonds may be issued under PNM's mortgage. The amount of SUNs that may be issued is not limited by the SUNs indenture. However, debt-to-capital requirements in certain of PNM's financial instruments and regulatory agreements would ultimately limit the amount of additional debt PNM would issue.

PNM currently has $46 million of tax-exempt bonds outstanding that were callable at a premium beginning December 15, 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 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 settled in cash 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 provided that the forecasted transactions (interest payments) occur as anticipated. The Company would seek regulatory approval to recover any hedge cost which could not be capitalized under the accounting rules in its next litigated electric rate proceeding.

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On November 1, 2002, the Company filed for approval from the PRC to enter into a transaction providing for the securitization of PNM's retail electric service accounts receivable, wholesale electric service accounts receivables and retail gas services accounts receivable ("Securitization") to reduce the amount of debt outstanding under the Credit Facility and to raise cash for PNM's ongoing working capital requirements and other capital requirements. The total capacity, or maximum that could be borrowed, under the Securitization will not exceed $100 million. In the proposed transaction, PNM would sell its accounts receivables from time to time. The PRC approved this request on December 17, 2002. The Company expects to enter into this transaction in March 2003.

PNM has notified the Holding Company that it intends to exercise its early buyout option related to its 60% ownership interest in the EIP transmission line and related facilities. In conjunction with the early buyout option, PNM will retire the related $26.2 million of 10.25% debt. PNM caused the related notification of mandatory redemptions to be distributed on February 24, 2003, calling the debt on April 1, 2003. Additionally, the Company acquired the remaining $12.5 million of publicly-traded EIP Secured Facility Bonds. These bonds have been retired and ownership of the related lease debt is expected to be transferred to PNM, subject to regulatory approvals.

Dividends

The Holding Company's board of directors regularly reviews the dividend policy. 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 the Holding Company. PNM cannot pay dividends that will cause its debt rating to go below investment grade; and PNM cannot pay dividends in any year, as determined on a rolling four-quarter basis, in excess of net earnings for that year without prior PRC approval. In January 2003, with the signing of the Global Electric Agreement, the PRC modified the PNM dividend restriction to allow PNM to dividend future equity contributions made by the Holding Company back to the Holding Company. Additionally, PNM has various financial covenants, which limit the transfer of assets, whether through dividends or other means.

In addition, the ability of the Holding Company to declare dividends is dependent upon the extent to which cash flows will support dividends, the availability of earnings, its financial circumstances and performance, the effect of regulatory decisions and legislative activities, future growth plans, the related capital requirements, standard business considerations and market and economic conditions generally.

Consistent with the PRC's holding company order, PNM paid dividends of $127.0 million to the Holding Company on December 31, 2001. On March 4, 2002, the PNM board of directors declared a dividend of $5.5 million, which was paid on 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% 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.

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Capital Structure

The Company's capitalization, including current maturities of long-term debt, at December 31, 2002 and 2001 are shown below:

                                         2002            2001
                                     -------------  -------------

Common Equity......................      49.2%           50.8%
Preferred Stock....................       0.7             0.6
Long-term Debt.....................      50.1            48.6
                                     -------------  -------------
   Total Capitalization*...........     100.0%          100.0%
                                     =============  =============

* Total capitalization does not include as debt the present value of PNM's operating lease obligations for PVNGS Units 1 and 2, EIP and the Delta operating lease, which was $196 million as of December 31, 2002 and $224 million as of December 31, 2001.

OTHER ISSUES FACING THE COMPANY

RESTRUCTURING THE ELECTRIC UTILITY INDUSTRY

State

In April 1999, the New Mexico Electric Utility Industry Restructuring Act of 1999 ("Restructuring Act") was enacted into law. The Restructuring Act opens the state's electric power market to customer choice. In March 2001, amendments to the Restructuring Act were passed which delayed the original implementation dates by approximately five years, including the requirement for corporate separation of supply service and energy-related service assets from distribution and transmission service assets. The Restructuring Act, as amended, will give schools, residential and small business customers the opportunity to choose among competing power suppliers beginning in January 2007. Competition would be expanded to include all customers starting in July 2007.

On October 10, 2002, PNM announced that it had agreed with the PRC Staff, the AG, and other consumer groups on the Global Electric Agreement that includes agreement to support repeal of a majority of the Restructuring Act, as amended. The Global Electric Agreement, which includes agreement on a five-year rate path, procedures for the Company's participation in merchant plant activities and other regulatory issues, was approved by the PRC on January 28, 2003. The New Mexico Legislature is currently in session. Legislation repealing the Restructuring Act, as amended, and continuing the authorization for utilities to participate in merchant plant activities for a limited time has been introduced as SB 718. On February 28, 2003, SB 718 passed the Senate by a vote of 37-2. It is now awaiting action in the House of Representatives. The Company is unable to predict at this time if restructuring will occur as provided in current law or, if so, what form it will take. (See "Merchant Plant Filing and Global Electric Agreement" below).

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The Restructuring Act, as amended, recognized 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. These stranded costs represent all costs associated with generation-related assets, currently in rates, in excess of the expected competitive market price over the life of those assets and include plant decommissioning costs, regulatory assets, and lease and lease-related costs. Utilities would 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 power supply and energy services businesses under the Restructuring Act, as amended, were established as regulatory assets. Because of the Company's belief that recovery is probable, these assets continue to be classified as regulatory assets, although the Company has discontinued the use of accounting for rate regulated activities. See Note 12 of the notes to consolidated financial statements for further developments.

Federal

The 107th Congress adjourned without passing comprehensive energy legislation. Both the House and the Senate passed energy legislation but were unable to resolve disagreement on a number of provisions during conference committee discussions. President Bush has expressed his continuing commitment to his National Energy Policy and has urged Congress to move forward with energy legislation. Key committee chairs in both the House and the Senate have expressed desires to move quickly on a comprehensive energy bill. The Company is unable to predict if energy legislation will be passed or if passed, what form it will take, or if it will be signed by the President if passed.

MERCHANT PLANT FILING AND GLOBAL ELECTRIC AGREEMENT

Senate Bill ("SB 266"), enacted by the 2001 session of the New Mexico legislature, allowed public utilities to "invest in, construct, acquire or operate" generating plants not intended to provide retail electric service ("merchant plant"), free of certain otherwise applicable regulatory requirements contained in the Public Utility Act. By order entered on March 27, 2001, the PRC found that these provisions of SB 266 raised issues such as cost allocations for ratemaking, revenue allocations for off-system sales, how the PRC can ensure the utility will meet its duty to provide service when the utility invests in merchant plant, how that plant will be financed and how transactions between regulated services and merchant plants will be conducted. The PRC initiated proceedings to address these issues.

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In November 2001, PNM began 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 resolves the issues surrounding industry deregulation in New Mexico and 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 to repeal the Restructuring Act and concerning merchant plant activities in the New Mexico Legislature. The Global Electric Agreement was approved by the PRC on January 28, 2003.

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. The Company expects to achieve necessary cost savings through additional cost efficiencies and fuel savings. The risks and benefits of all wholesale electric sales, inure solely to the Company's shareholders until December 2007. Since the 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 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.

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.

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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 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 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.

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 charge of approximately $16.7 million, pre-tax, in the first quarter of 2003.

In the Global Electric Agreement, PNM, PRC utility staff and intervenors agreed to actively support the repeal of a majority of the Restructuring Act, as amended. Legislation repealing the Restructuring Act, as amended, and continuing authorization for utilities to participate in merchant plant for a limited time has been introduced as SB 718. On February 28, 2003, SB 718 passed the Senate by

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a vote of 37-2. It is now awaiting action in the House of Representatives. 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.

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.

WATER SUPPLY

There is a growing concern in New Mexico about the use of water for power plants, due to the state's arid climate and current drought conditions. The availability of sufficient water supplies to meet all the needs of the state, including growth, is a major issue. An interim committee of the legislature refused to support legislation mandating the use of dry cooling technology. However, legislation requiring a water conservation plan as part of an application for siting generation plants of a certain size is being considered in the 2003 session. In building the Afton and Lordsburg plants, the Company has secured sufficient water rights.

The Four Corners region, in which SJGS and Four Corners are located, has been experiencing drought conditions that may affect the water supply for the plants in 2003, as well as later years if adequate moisture is not received in the watershed that supplies the area. USBR is working to assess the adequacy of the water supply under PNM's USBR contract for 16,200 acre feet of water that supplies SJGS. Additionally, various stakeholders in the San Juan Basin, including the New Mexico State Engineer, are evaluating what water rights might be affected by the drought conditions, including water rights pursuant to the New Mexico state permit that provide 8,000 acre feet of water to SJGS and approximately 28,000 acre feet of water for Four Corners. PNM is assessing alternatives for temporary supplies of water and is working with USBR and area stakeholders to minimize the effect on operations of the plants. PNM has assessed its situation with regard to the drought and the alternatives available to it and does not believe that its operations will be materially affected at this time. However, PNM cannot forecast the weather situation and its ramifications with any degree of certainty or how regulators and legislators may impact PNM's situation in the future, should the drought continue.

WESTERN UNITED STATES WHOLESALE POWER MARKET

A significant portion of the Company's earnings in 2001 was derived from the Company's wholesale power marketing operations, which benefited from strong demand and high wholesale prices in the Western United States. These market conditions were driven by a number of separate factors, including electric power

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supply shortages in the Western United States during the first half of 2001, weather conditions, gas supply costs and transmission constraints. As a result of these factors, the wholesale power market in the Western United States became extremely volatile and, while providing many marketing opportunities, presented and continues to present significant risk to companies selling power into this marketplace.

These conditions resulted in the well-publicized "California energy crisis" and in the bankruptcy filings of the California Power Exchange ("Cal PX") and of Pacific Gas and Electric Company ("PG&E"), although the turmoil in the Western markets was not limited to California. However, since the third quarter of 2001, conditions in the Western wholesale power market have changed substantially as the result of certain regulatory actions (see below), moderate weather conditions, conservation measures, the construction of additional generation, and a decline in natural gas prices, as well as the lingering slowdown in the regional economy. These changes have placed and are expected to continue to place downward pressure on wholesale electricity prices.

In response to the turmoil in the Western energy market, the FERC initially imposed a "soft" price cap of $150 per MWh for sales to the Cal PX and the California Independent System Operator ("Cal ISO") that required any wholesale sales of electricity into these markets be capped at $150 per MWh unless the seller could demonstrate that its costs exceeded the cap. This price cap was modified by orders of the FERC that directed certain power suppliers to provide refunds for overcharges calculated on the basis of a formula that sanctioned wholesale prices considerably in excess of the $150 per MWh level. Shortly thereafter, the FERC adopted an order establishing prospective mitigation and a monitoring plan for the California wholesale markets and which established a further investigation of public utility rates in wholesale Western energy markets. This plan replaced the $150 per MWh soft cap previously established and applied during periods of system emergency. Subsequently, the FERC issued still another order that changed the previous orders and expanded the price mitigation approach to the entire Western region.

In July 2002, the FERC issued further orders to address wholesale power prices in the Western market. On July 11, the FERC established a price cap of $91.87 per MWh for the period ending September 30, 2002. On July 17, the FERC entered an order, which was to have taken effect October 1, 2002, raising the price cap to $250 per MWh. However, the FERC extended the $91.87 per MWh price cap through October 31, 2002. According to the FERC, this price cap will spur new investment in generation and will foster the eventual return of a robust competitive marketplace. The July 17 order also established mechanisms to prevent power suppliers from engaging in market manipulation activities.

As a result of the foregoing conditions in the Western market, the FERC and other federal and state governmental authorities are conducting investigations and other proceedings relevant to the Company and other sellers. The more significant of these in relation to the Company are summarized below.

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California Refund Proceeding

By order dated June 19, 2001, in response to a complaint filed by San Diego Gas and Electric Company ("SDG&E") and other California buyers against sellers into the California wholesale electric market, the FERC directed one of its administrative law judges ("ALJ") to convene a settlement conference to address potential refunds owed by sellers into the California market. The settlement conference, in which PNM participated, was ultimately unsuccessful, and the ALJ recommended to the FERC that an evidentiary hearing be held to resolve the dispute, suggesting that refunds were due; however, the estimated refunds were significantly lower than those demanded by California, and in most instances, were offset by the amounts due suppliers from the Cal PX and Cal ISO. The California parties had demanded refunds of approximately $9 billion from power suppliers. Hearings on the refunds were held in September 2002 and the ALJ issued his Proposed Findings on California Refund Liability on December 12, 2002, in which he determined that the Cal ISO had, for the most part, calculated the amounts of the refunds correctly. In his appendix identifying the amounts of the refunds, he identified what he termed "ballpark" figures for the amount of refunds due under his order. PNM was identified as having a refund liability of approximately $4.3 million, while being owed approximately $7 million from the Cal ISO. Pursuant to the FERC's order, PNM filed, in conjunction with the competitive supplier group, initial comments on January 13, 2003 to the ALJ's preliminary findings addressing errors the Company believes the ALJ made in his proposed findings and reply comments on February 3, 2003. Prior to the December 12, 2002 ALJ decision, the Ninth Circuit Court of Appeals ordered FERC to allow the parties in the case to provide additional evidence in the case. Several California parties submitted additional evidence on March 3, 2003, which they argue supports their position that virtually all market participants either engaged in specific market manipulation strategies or facilitated such strategies, including PNM. PNM maintains that it did not engage in improper wholesale trading activities. PNM, along with other members of the competitive supplier group, will file reply evidence on March 20, 2003. PNM cannot predict what effect this additional evidence will have on the prior decision of the ALJ as to specific refund amounts. The Company is unable to predict the ultimate outcome of this FERC proceeding, or whether PNM will be directed to make any refunds as the result of a FERC order.

Pacific Northwest Refund Proceeding

In addition to the California refund proceedings, Puget Sound Energy, Inc., filed a complaint at FERC alleging that spot market prices in the Pacific Northwest wholesale electric market were unjust and unreasonable. On September 24, 2001, the ALJ issued a recommended decision and declined to order refunds associated with wholesale electric sales in the Pacific Northwest. Prior to the FERC acting on the ALJ's recommended decision, several parties joined in filing a motion at the FERC requesting the FERC to reopen the proceeding, in view of the issuance of the FERC Staff's report on the Enron trading strategies, to permit further investigation and discovery into transactions in the wholesale electric market in the Pacific Northwest. The FERC re-opened the docket to receive additional evidence from the parties. The FERC did not remand the case to the ALJ, but determined to undertake themselves the review of any additional evidence in conjunction with the ALJ's recommended decision. On March 3, 2003, Puget Sound and other parties submitted additional evidence to FERC alleging the existence of unlawful wholesale electric prices in the Pacific Northwest and that FERC should require sellers to provide refunds for spot market bilateral

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sales transactions in the Pacific Northwest. The Company believes there is nothing in this additional evidence that requires FERC to reverse the prior decision of the ALJ denying refunds. The Company is unable to predict the ultimate outcome of this FERC proceeding, or whether PNM will be directed to make any refunds as the result of an order by the FERC.

FERC Investigation of "Enron-Like" Trading Practices

The FERC has also initiated a market manipulation investigation, partially in response to the bankruptcy filing of the Enron Corporation ("Enron") and to allegations that Enron may have engaged in manipulation of portions of the Western wholesale power market. In connection with that investigation, all FERC jurisdictional and non-jurisdictional sellers into Western electric and gas markets have been required to submit data regarding short-term transactions in 2000-2001. PNM made its data submission on April 2, 2002. Subsequently, in May 2002, new Enron documents came to light that raised additional concerns about Enron's trading practices. In light of these new revelations, the FERC issued additional orders in the pending investigation requiring sellers to respond to detailed questions by admitting or denying that they had engaged in trading practices similar to those practiced by Enron and certain other sellers, including so-called "wash" transactions. The FERC issued supplemental requests for data submissions. In its responses to the FERC requests, PNM denied that it had engaged in improper activities such as those identified in Enron's memos and also denied engaging in "wash" transactions. PNM admitted engaging in certain activities described in the memos that were not improper. Where appropriate, PNM's responses addressed any arguable similarities between any of its trading activities and those under investigation by the FERC. The FERC staff has issued a preliminary report on its findings, recommending that the FERC initiate formal investigative proceedings directed at three companies and the FERC has done so. The Company was not among the companies named. The Company cannot predict the outcome of this investigation.

California Power Exchange and Pacific Gas and Electric Bankruptcies

In January and February 2001, SCE and PG&E, major purchasers of power from the Cal PX and Cal ISO, defaulted on payments due the Cal PX for power purchased from the Cal PX in 2000. These defaults caused the Cal PX to seek bankruptcy protection. PG&E subsequently also sought bankruptcy protection. PNM has filed its proofs of claims in the Cal PX and PG&E bankruptcy proceedings. Total amounts due PNM from the Cal PX or Cal ISO for power sold to them in 2000 and 2001 total approximately $7 million. The Company has provided allowances for the total amount due from the Cal PX and Cal ISO.

California Attorney General Complaint

In March 2002, the California Attorney General filed a complaint with the FERC against numerous sellers regarding prices for wholesale electric sales into the Cal ISO and Cal PX and to the California Department of Water Resources ("Cal DWR"). PNM was among the sellers identified in this complaint and filed its answer and motion to intervene. In its answer, PNM defended its pricing and challenged the theory of liability underlying the California Attorney General's

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complaint. On May 31, 2002, the FERC entered an order denying the California Attorney General's request to initiate a refund proceeding, but directed sellers, including PNM, to comply with additional reporting requirements with regard to certain wholesale power transactions. PNM has made filings required by the May 31, 2002 order. The California Attorney General filed a request for rehearing contesting the FERC decision. On September 23, 2002, the FERC issued its order denying the California Attorney General's request for rehearing. The California Attorney General has filed a petition for review in the United States Court of Appeals for the Ninth Circuit. PNM has intervened in the Ninth Circuit appeal and intends to participate as a party in that proceeding. The Company cannot predict the outcome of this appeal. As addressed below, the California Attorney General has also threatened litigation against PNM in state court in California based on similar allegations.

California Attorney General Threatened Litigation

The California Attorney General has filed several lawsuits in California state court against certain power marketers for alleged unfair trade practices involving alleged overcharges for electricity. By letter dated April 9, 2002, the California Attorney General notified PNM of its intention to file a complaint in California state court against PNM concerning its alleged failure to file rates for wholesale electricity sold in California and for allegedly charging unjust and unreasonable rates in the California markets. The letter invited PNM to contact the California Attorney General's office before the complaint was filed, and PNM has met several times with representatives of the California Attorney General's office. Further discussions are contemplated. To date, a lawsuit has not been filed by the California Attorney General and the Company cannot predict the outcome of this matter.

California Antitrust Litigation

Several class action lawsuits have been filed in California state courts against electric generators and marketers, alleging that the defendants violated the law by manipulating the market to grossly inflate electricity prices. Named defendants in these lawsuits include Duke Energy Corporation ("Duke") and related entities along with other named sellers into the California market and numerous other "unidentified defendants." These lawsuits were consolidated for hearing in state court in San Diego. In May 2002, the Duke defendants in the foregoing state court litigation served a cross-claim on PNM. Duke also cross-claimed against many of the other sellers into California. Duke asked for declaratory relief and for indemnification for any damages that might ultimately be imposed on Duke. Several defendants removed the case to federal court. The federal judge has entered an order remanding the matter to state court, but the filing of various procedural motions has delayed the effect of this ruling. PNM has joined with other cross-defendants in motions to dismiss the cross-claim. The Company believes it has meritorious defenses but cannot predict the outcome of this matter.

Block Forward Agreement Litigation

On February 1, 2002, PNM was served with a declaratory relief complaint filed by the State of California in California state court. The state's declaratory relief complaint seeks a determination that the state is not liable

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for its commandeering of certain energy contracts known as "Block Forward Agreements". The Block Forward Agreements were a form of futures contracts for the purchase of electricity at below-market prices and served as security for payment by PG&E and SCE for their electricity purchases through the Cal PX. When PG&E and SCE defaulted on payment obligations incurred through the Cal PX, the Cal PX moved to liquidate the Block Forward Agreements to satisfy in part the obligations owed by PG&E and SCE. Before the Cal PX could liquidate the Block Forward Agreements, California commandeered them for its own purposes. In March 2001, PNM and other similarly situated sellers of electricity through the Cal PX filed claims for damages with the California state Victims Compensation and Government Claims Board ("Victims Claims Board") on the theory that the state, by commandeering the Block Forward Agreements, had deprived them of security to which they were entitled under the terms of the Cal PX's tariff. The Victims Claims Board filing was an administrative remedy that served as a mandatory prerequisite to filing suit against the state for recovery of damages related to the commandeering of the Block Forward Agreements. The Victims Claims Board denied PNM `s claim on March 22, 2002. PNM filed a complaint against the State of California in California state court on September 20, 2002 seeking damages for the state's commandeering of the Block Forward Agreements and requesting judicial coordination with the state's declaratory relief action filed in February 2002 on the basis that the two actions raise essentially the same issues. The California State court stayed the proceedings through April 11, 2003 pending resolution of certain related issues before the FERC.

Effects of Certain Events on Future Revenues

On October 1, 1999, Western Area Power Administration ("WAPA") filed a petition at the FERC requesting the FERC to order PNM to provide network transmission service to WAPA under PNM's Open Access Transmission Tariff on behalf of the United States Department of Energy ("DOE") as contracting agent for Kirtland Air Force Base ("KAFB").

On April 29, 2002, the FERC issued its Final Order directing PNM to provide the service. The Company filed an appeal of the April 29th order in the United States Court of Appeals for the 10th Circuit. The Company, USEA and WAPA entered a binding memorandum of understanding resolving the dispute. The memorandum provided that upon approval by the PRC of the Agreement resolving the Company's electric rate path and merchant plant issues described earlier in (wherever it is described), the Company would dismiss its appeal at the Tenth Circuit and WAPA would purchase from the Company approximately 60 MW of electric power that will be wheeled under the FERC Final Order to serve KAFB. The power sales agreement between the Company and WAPA was executed on February 3, 2003. On March 1, 2003 the power sales agreement went into effect and the Company dismissed its appeal at the 10th Circuit on March 5, 2003.

Due to the price difference between New Mexico jurisdictional retail sales rates and the wholesale rates under the power sales agreement between the Company and WAPA, the loss in revenue is expected to be $2.8 million per year beginning in 2004.

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In a separate but related proceeding, PNM and the United States Executive Agencies on behalf of KAFB are involved in a PRC case regarding a dispute over specific Company tariff language under which PNM provides service to KAFB. The PRC case was held in abeyance, pending the outcome of the FERC proceeding. A status conference is scheduled before the PRC Hearing Examiner to determine how to proceed with the case due to the dismissal of the Tenth Circuit appeal and implementation of the power sales agreement between Wapa and the Company.

NEW SOURCE REVIEW RULES

In November 1999, the Department of Justice at the request of the Environmental Protection Agency ("EPA") filed complaints against seven companies alleging the companies over the past 25 years had made modifications to their plants in violation of the New Source Review ("NSR") requirements and in some cases the New Source Performance Standard ("NSPS") regulations, which could result in the requirement to make costly environmental additions to older power plants. Whether or not the EPA will prevail is unclear at this time. The EPA has reached a settlement with one of the companies sued by the Justice Department. Discovery continues in the pending litigation, several of the pending cases are approaching trial, and a trial has commenced in one of the cases. No complaint has been filed against PNM by the EPA, and the Company believes that all of the routine maintenance, repair, and replacement work undertaken at its power plants was and continues to be in accordance with the requirements of NSR and NSPS. However, by letter dated October 23, 2000, the New Mexico Environmental Department ("NMED") made an information request of PNM, advising PNM that the NMED was in the process of assisting the EPA in the EPA's nationwide effort "of verifying that changes made at the country's utilities have not inadvertently triggered a modification under the Clean Air Act's Prevention of Significant Determination ("PSD") policies." PNM has responded to the NMED information request. In late June 2002, PNM received another information request from the NMED for a list of capital projects budgeted or completed in 2001 or 2002. PNM has responded to this additional NMED information request.

The National Energy Policy released in May 2001 by the National Energy Policy Development Group called for a review of the pending EPA enforcement actions. As a result of that review, on June 14, 2002, the EPA announced its intention to pursue steps to increase energy efficiency, encourage emissions reductions and make improvements and reforms to the NSR program. The EPA announced that, among other things, the NSR program had impeded or resulted in the cancellation of projects that would maintain or improve reliability, efficiency and safety of existing power plants. The EPA's June 2002 announcement contemplated further rulemakings on NSR-related issues and expressly cautioned that the announcement was not intended to affect pending NSR enforcement actions. Thereafter, on December 31, 2002, the EPA promulgated certain long-awaited revisions to the NSR rules, along with proposals to revise the routine maintenance, repair and replacement exclusion contained in the regulations. There is no specific timetable for these revisions and the ultimate resolution of NSR-related issues raised by the enforcement actions remains unclear. If the EPA were to prevail in the position advanced in the pending litigation, the Company may be required to make significant capital expenditures, which could have a material adverse effect on the Company's financial position and results of operations.

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Citizen Suit Under the Clean Air Act

By letter dated January 9, 2002, counsel for the Grand Canyon Trust and Sierra Club (collectively, "GCT") notified PNM of GCT's intent to file a so-called "citizen suit" under the Clean Air Act, alleging that PNM and co-owners of the SJGS violated the Clean Air Act, and the implemention of federal and state regulations, at SJGS. Pursuant to that notification, on May 16, 2002, the GCT filed suit in federal district court in New Mexico against PNM (but not against the other SJGS co-owners). The suit alleges two violations of the Clean Air Act and related regulations and permits. First, GCT argues that the plant has violated, and is currently in violation of, the federal PSD rules, as well as the corresponding provisions of the New Mexico Administrative Code, at SJGS Units 3 and 4. Second, GCT alleges that the plant has "regularly violated" the 20% opacity limit contained in SJGS's operating permit and set forth in federal and state regulations at Units 1, 3 and 4. The lawsuit seeks penalties as well as injunctive and declaratory relief. PNM filed its answer in federal court on June 6, 2002, denying the material allegations in the complaint. Both sides in the litigation have filed motions for partial summary judgment, but the court has, to date, made no rulings on any of these matters. A trial date on liability issues has been scheduled on a trailing docket for June 2003. Based on its investigation to date, the Company firmly believes that the allegations are without merit and PNM vigorously disputes the allegations. PNM has always adhered and continues to adhere to high environmental standards as evidenced by its ISO 14000 certification. The Company is, however, unable to predict the ultimate outcome of the matter.

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 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.

LANDOWNER ENVIRONMENTAL CLAIMS

In March 2002, a lawsuit was filed in New Mexico state court by a landowner owning property in the vicinity of SJGS, against PNM and SJCC. The lawsuit was served on the defendants on June 11, 2002. The complaint seeks $20 million in damages, plus pre-judgment interest and punitive damages, based on allegations related to the alleged discharge of pollutants into an arroyo near

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the plant, including damage to the plaintiff's livestock. A jury trial has been demanded. PNM has denied the allegations of wrongdoing and is vigorously defending this matter, but is unable to predict the outcome of this matter.

ARCHEOLOGICAL SITE DISTURBANCE

The Company hired a contractor, Great Southwestern Construction, Inc. ("Great Southwestern"), to conduct certain "climb and tighten" activities on a number of electric transmission lines in New Mexico between July 2001 and December 2001. Those lines traverse a mix of federal, state, tribal and private properties in New Mexico. In late May 2002, the U.S. Forest Service ("USFS") notified PNM that apparent disturbances to archeological sites had been discovered in and around the rights-of-way for PNM's transmission lines in the Carson National Forest in New Mexico. Great Southwestern performed "climb and tighten" activities on those transmission lines. PNM has confirmed the existence of the disturbances, as well as disturbances associated with certain arroyos that may raise issues under section 404 of the Clean Water Act. PNM has given the Corps of Engineers notice concerning the disturbances in arroyos. The Corps of Engineers has acknowledged the Company's notice and asked PNM to cooperate in addressing these disturbances. No formal or written demand by the USFS has been made on the Company with respect to this matter, but the USFS has verbally instructed PNM to undertake an assessment and possible related mitigation measures with respect to the archeological sites in question. PNM contracted for an archeological assessment and a proposed remediation plan with respect to the disturbances and has provided the assessment to the USFS and the federal Bureau of Land Management ("BLM"). PNM has provided Great Southwestern with notice and a demand for indemnity. A subsequent preliminary investigation into other transmission lines that were covered by the "climb and tighten" project indicated that there are disturbances on lands governed by other federal agencies and Indian tribes. PNM and Great Southwestern have provided notice of the potential disturbances to these other agencies and tribes. No formal action has been initiated against PNM and no notice of any contemplated action has been received. The Company had been informed that the USFS and BLM had commenced a criminal investigation into Great Southwestern's activities on this project. However, the Company recently received verbal confirmation that the USFS and the BLM have decided to decline criminal prosecution. The State of New Mexico recently requested information from PNM concerning the location of potential disturbances on state lands. The Navajo Nation has also requested further information concerning disturbances on Navajo land. The Company is unable to predict the outcome of this matter and cannot estimate with any certainty the potential impact on the Company's operations.

DUGAN PRODUCTION CORPORATION LITIGATION

On July 30, 2002, Dugan Production Corp. filed a lawsuit in the County of San Juan, New Mexico, against the SJCC. On September 2, 2002, the SJCC removed the lawsuit to the United States District Court for the District of New Mexico. The lawsuit seeks to enjoin the underground mining of coal from a portion of the land that is to be used for the underground mine. The plaintiff also seeks monetary damages.

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The SJCC, through leases with the federal government and the State of New Mexico, owns coal interests with respect to the underground mine. The plaintiff, through leases with the federal government, the State of New Mexico and certain private parties, claims to own certain oil and gas interests in portions of the land that is to be used for the underground mine. The plaintiff alleges that the SJCC's underground coal mining operations have or will interfere with plaintiff's gas production and result in the dissipation of natural gas that it otherwise would be entitled to recover. The plaintiff also alleges, and seeks a declaration by the court, that the rights under its leases are senior and superior to the rights of the SJCC.

The SJCC has informed the Company that SJCC intends to vigorously dispute the litigation. On September 17, 2002, the SJCC filed a motion to dismiss the claims against it on several grounds. Discovery for the lawsuit has not yet started. The Company cannot predict the ultimate outcome of the litigation or whether the litigation will adversely affect the amount of coal available, or its price for SJGS.

EXCESS EMISSIONS REPORTS

As required by law, whenever there are excess emissions from SJGS, due to such causes as start-up, shutdown, upset, breakdown or certain other conditions, PNM makes filings with the NMED. For some two years, PNM has been in discussions with NMED concerning excess emissions reports for the period after January 1997. NMED is still in the process of investigating the circumstances of these excess emissions and whether these emissions involve any violation of applicable permits and regulations. PNM and NMED have entered into several agreements tolling the running of the statute of limitations in order to allow NMED to complete its review of these filings. The present tolling agreement expires March 14, 2003. PNM has been advised by NMED counsel that NMED is in the process of preparing a draft administrative compliance order addressing certain claimed violations, but PNM has not seen this draft order and has not had a chance to meet with NMED to address any violations that might be claimed. The Company is unable to predict the outcome of this matter and cannot estimate the potential impact on the Company's operations.

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

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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.

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

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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.

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

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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.

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 ("SFAS 133") "Accounting for Derivative Instruments and Hedging Activities". 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 adjustment in the period of adoption. This transition provision will be effective for the first quarter of 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 is reviewing its energy contract portfolio to determine whether its contracts meet the definition of trading activities under EITF 02-3 which should be presented on a net margin basis. The Company will reclassify prior periods to a net margin basis for those contracts previously accounted for under EITF 98-10 in the first quarter of 2003. The Company does not expect to 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 of Company's marketing activities meet the definitions of trading activities as prescribed by EITF 02-3.

DISCLOSURE REGARDING FORWARD LOOKING STATEMENTS

Statements made in this filing that relate to future events 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 are subject to risk and uncertainties. The Company assumes no obligation to update this information.

Because actual results may differ materially from expectations, the Company cautions readers not to place undue reliance on these statements. Future financial results will be affected by a number of factors, including 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, and the performance of state, regional and national economies.

81

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

The Company uses derivative financial instruments to manage risk as it relates to changes in natural gas and electric prices, changes in interest rates and, historically, adverse market changes for investments held by the Company's various trusts. The Company also uses certain derivative instruments for wholesale power marketing transactions in order to take advantage of favorable price movements and market timing activities in the wholesale power markets. The following additional information is provided.

Risk Management

The Company controls the scope of its various forms of risk through a comprehensive set of policies and procedures and oversight by senior level management and the Holding Company Board of Directors. The Board's Finance Committee sets the risk limit parameters. The Risk Management Committee ("RMC"), comprised of corporate and business segment officers and other managers, oversees all of the activities, which include commodity price, credit, equity, interest rate and business risks. The RMC has oversight for the ongoing evaluation of the adequacy of the risk control organization and policies. The Company has a risk control organization, headed by the Director of Financial Risk Management ("Risk Manager"), which is assigned responsibility for establishing and enforcing the policies, procedures and limits and evaluating the risks inherent in proposed transactions, on an enterprise-wide basis.

The RMC's responsibilities specifically include: establishment of a general policy regarding risk exposure levels and activities in each of the business segments; recommendation of the types of instruments permitted; authority to establish a general policy regarding counterparty exposure and limits; authorization and delegation of transaction limits; review and approval of controls and procedures; review and approval of models and assumptions used to calculate mark-to-market and risk exposure; authority to approve and open brokerage and counterparty accounts; review of hedging and risk activities; and quarterly reporting to the Finance Committee and the Board of Directors on these activities.

The RMC also proposes Value at Risk ("VAR") limits to the Finance Committee. The Finance Committee ultimately sets the aggregate VAR limit.

It is the responsibility of each business unit to create its own control procedures and policies within the parameters established by the Finance Committee. The RMC reviews and approves these policies, which are created with the assistance of the Chief Accounting Officer, Director of Internal Audit and the Risk Manager. Each business unit's policies address the following controls:
authorized risk exposure limits; authorized instruments and markets; authorized personnel; policies on segregation of duties; policies on mark-to-market accounting; responsibilities for deal capture; confirmation procedures; responsibilities for reporting results; statement on the role of derivative transactions; and limits on individual transaction size (nominal value).

82

To the extent an open position exists, fluctuating commodity prices can impact financial results and financial position, either favorably or unfavorably. As a result, the Company cannot predict with precision the impact that its risk management decisions may have on its businesses, operating results or financial position.

Commodity Risk

Marketing and procurement of energy often involves market risks associated with managing energy commodities and establishing open positions in the energy markets, primarily on a short-term basis. These risks fall into three different categories: price and volume volatility, credit risk of counterparties and adequacy of the control environment. PNM routinely enters into forward contracts and options to hedge purchase and sale commitments, fuel requirements and to minimize the risk of market fluctuations on the Generation and Marketing Operations.

The Company's wholesale power marketing operations, including both long-term contracts and merchant sales activities, are managed through an asset-backed marketing strategy, whereby PNM's aggregate net open forward contract position is covered by its own excess generation capabilities. PNM is exposed to market risk if its generation capabilities were disrupted or if its retail load requirements were greater than anticipated. If PNM were required to cover all or a portion of its net open contract position, it would have to meet its commitments through market purchases.

Under the derivative accounting rules and the related accounting rules for energy contracts, the Company accounts for its various financial derivative instruments for the purchase and sale of energy differently based on management's intent when entering into the contract. Energy contracts which meet the definition of a derivative under SFAS 133 and do not qualify for a normal purchase or sale designation are recorded on the balance sheet at fair market value at each period end. The changes in fair market value are recognized in earnings unless specific hedge accounting criteria are met. Should an energy transaction qualify as a hedge, fair market value changes from year to year are recognized on the balance sheet with a corresponding charge to other comprehensive income. Gains or losses are recognized when the hedged transaction occurs. Normal purchases and sales are not marked to market but rather recorded in results of operations when the underlying transaction occurs.

(Intentionally left blank)

83

The following table shows how the net fair value of mark-to-market energy contracts was derived from the amounts included in the balance sheet:

                                                            Year Ended
                                                            December 31,
                                                         2002          2001
                                                     -----------   ------------
                                                          (In thousands)
Mark-to-Market Energy Contracts:
   Current asset....................................  $  4,531       $  9,461
   Long-term asset..................................       267          1,469
                                                     -----------   ------------
      Total mark-to-market assets...................     4,798         10,930
                                                     -----------   ------------
   Current liability................................    (5,725)       (36,256)
   Long-term liability..............................         -         (5,114)
                                                     -----------   ------------
      Total mark-to-market liabilities..............    (5,725)       (41,370)
                                                     -----------   ------------
Net fair value of mark-to-market energy contracts...   $  (927)     $ (30,440)
                                                     ===========   ============

The mark-to-market energy portfolio positions at December 31, 2002 and December 31, 2001 represent net liabilities after netting all open purchase and sale contracts. Because the contractual amounts required to settle the open net liability were greater than the current market values of the contracts, the Company recorded a net loss position in 2002 and 2001; however, the settlement of certain of these transactions in 2002 and changes in market prices significantly reduced the loss position and resulted in the recognition of a mark-to-market gain.

The market prices used to value PNM's mark-to-market energy portfolio are based on closing exchange prices and over-the-counter quotations. As of December 31, 2002 and December 31, 2001, PNM did not have any outstanding contracts that were valued using methods other than quoted prices. The Company did not change its methods for valuing its mark-to-market energy portfolio in 2002 as compared to 2001.

The following table provides detail of changes in the Company's mark-to-market energy portfolio net asset or liability balance sheet position from one period to the next:

                                                       Year Ended
                                                      December 31,
                                                 2002             2001
                                               ------------    ------------
                                                      (In thousands)
Sources of Fair Value Gain/(Loss)
Fair value at beginning of year...............  $ (30,440)       $ (4,643)
Amount realized on contracts delivered
   during period..............................     26,339           2,239
Changes in fair value.........................      3,174         (28,036)
                                               ------------    ------------
Net fair value at end of period...............   $   (927)       $(30,440)
                                               ============    ============
Net change recorded as mark-to-market.........   $ 29,513        $(25,797)
                                               ============    ============

84

This table provides the maturity of the net assets/liabilities of the Company, giving an indication of when these mark-to-market amounts will settle and generate/(use) cash:

Fair Value at December 31, 2002

                                               Maturities
                                 -----------------------------------------
                                 Less than
Sources of Fair Value              1 year       1-3 Years        Total
-------------------------------  -----------  -------------  -------------
                                              (In thousands)

Mark-to-market energy contracts     $(1,194)       $  267        $ (927)

Note: All values determined using broker quotes.

As of December 31, 2002, a decrease in market pricing of PNM's mark-to-market energy portfolio by 10% would have resulted in a decrease in net earnings of less than 1%. Conversely, an increase in market pricing of this portfolio by 10% would have resulted in an increase in net earnings of less than 1%.

At December 31, 2002, the market value of PNM's normal sales and purchases of electricity was a $54.6 million asset using the valuation methods described above. If these transactions did not meet the definition of normal under the accounting rules for derivatives, the Company would have recognized unrealized gains of $56.3 million as an adjustment to Generation and Marketing operating revenues based on the change in fair value of these contracts from January 1, 2002 to December 31, 2002.

The Company assesses the risk of these long-term contracts and merchant sales activities using the VAR method to maintain the Company's total exposure within management-prescribed limits. The Company utilizes the variance/covariance model of VAR, which is a probabilistic model that measures the risk of loss to earnings in market sensitive instruments. The variance/covariance model relies on statistical relationships to analyze how changes in different markets can affect a portfolio of instruments with different characteristics and market exposure. VAR models are relatively sophisticated; however, the quantitative risk information is limited by the parameters established in creating the model. The instruments being evaluated may trigger a potential loss in excess of calculated amounts if changes in commodity prices exceed the confidence level of the model used. The VAR methodology employs the following critical parameters: volatility estimates, market values of open positions, appropriate market-oriented holding periods and seasonally adjusted correlation estimates. The Company's VAR calculation only considers the Company's forward position for the proceeding eighteen months. The Company uses a holding period of three days as the estimate of the length of time that will be needed to liquidate the positions. The volatility and the correlation estimates measure the impact of adverse price movements both at an individual position level as well as at the total portfolio level. The confidence level established is 99%. For example, if VAR is calculated at $10 million, it is estimated at a 99% confidence level that if prices move against PNM's positions, the Company's pre-tax gain or loss in liquidating the portfolio would not exceed $10 million in the three days that it would take to liquidate the portfolio.

85

The Company's VAR is regularly monitored by the Company's RMC. The RMC has put in place procedures to ensure that increases in VAR are reviewed and, if deemed necessary, acted upon to reduce exposures. The VAR represents an estimate of the potential gains or losses that could be recognized on PNM's wholesale power marketing portfolios given current volatility in the market, and is not necessarily indicative of actual results that may occur, since actual future gains and losses will differ from those estimated. Actual gains and losses may differ due to actual fluctuations in market rates, operating exposures, and the timing thereof, as well as changes to PNM's wholesale power marketing portfolios during the year.

The Company accounts for the sale of electric generation in excess of its retail needs or the purchase of power for retail needs as normal purchases and sales under SFAS 133. Purchases for resale and subsequent resales are accounted for as energy trading contracts in accordance with EITF 98-10 and comprise PNM's mark-to-market portfolio. The VAR for the mark-to-market portfolio was $72,027 at December 31, 2002. The Company also calculates a portfolio VAR, which in addition to its mark-to-market portfolio includes all contracts designated as normal sales and purchases, hedges, and its estimated excess generation assets. This excess is determined using average peak forecasts for the respective block of power in the forward market. The Company's portfolio VAR was $2.0 million at December 31, 2002.

The following table shows the high, average and low market risk as measured by VAR on the Company's mark-to-market portfolio (three day holding period, 99% two-tailed confidence level):

                 Year Ended
              December 31, 2002
-----------------------------------------
   High            Average         Low
------------    ------------    ---------
                (In thousands)

    $3,408          $1,112          $29

Credit Risk

PNM is exposed to credit losses in the event of non-performance or non-payment by counterparties. The Company uses a credit management process to assess and monitor the financial conditions of counterparties. Credit exposure is also regularly monitored by the RMC. The Company provides for losses due to market and credit risk. PNM's credit risk with its largest counterparty as of December 31, 2002 was $18.7 million.

In 2001, in response to the increased credit risk and market price volatility described above, the Company provided an allowance against revenue of $12.0 million for anticipated losses to reflect management's estimate of the increased market and credit risk in the wholesale power market and its impact on 2001 revenues. As of December 31, 2001, $8.9 million was transferred to the allowance for bad debt. The Company reduced its reserves by $0.6 million for the year ended December 31, 2002 as a result of a lack of market liquidity, lower prices and lower volatility. Based on information available at December 31, 2002, the Company believes the total allowance for anticipated losses (exclusive of bad debt), currently established at $2.4 million, is adequate for management's estimate of losses from credit risk. The Company will continue to monitor the wholesale power marketplace and adjust its estimates accordingly.

86

The following table provides information related to PNM's credit exposure, net of collateral as of December 31, 2002. It further delineates that exposure by the credit worthiness (credit rating) of the counterparties and provides guidance as to the concentration of credit risk to individual counterparties PNM may have.

Schedule of Wholesale Power Marketing Credit Risk Exposure December 31, 2002

                                                                                    Net
                           Exposure                                  Number      Exposure
                            Before                                     of          of
                            Credit         Credit                   Counter-     Counter-
                          Collateral     Collateral  Net Exposure    parties      parties
Rating (a)                    (b)            (c)                      >10%         >10%
------------------------  -----------   ------------  -----------  -----------  -----------
                                           (Dollars in thousands)
Investment grade........     $35,397         $    -      $35,397        1          $18,732
Non-investment grade           4,837              -        4,837                         -
Split rating............          20              -           20                         -
Internal ratings
   Investment grade.....         635              -          635                         -
   Non-investment
     grade..............      15,446            211       15,235         1           6,096
                          -----------   ------------  -----------               -----------
        Total...........     $56,335        $   211      $56,124                   $24,828
                          ===========   ============  ===========               ===========
Credit reserves                                          $ 2,433
                                                      ===========

(a) Rating - Included in "Investment Grade" are counterparties with a minimum Standard & Poor's rating of BBB- or Moody's rating of Baa3. If the counterparty has provided a guarantee by a higher rated entity (e.g., its parent), determination is based on the rating of its guarantor. The "Internal Ratings - Investment Grade" includes those counterparties that are internally rated as investment grade in accordance with the guidelines established in the Company's credit policy.

(b) The Exposure Before Credit Collateral is the net credit exposure to PNM from its wholesale power marketing activities. This includes long-term contracts and other merchant sales and purchases. The exposure captures the net amounts due to PNM from receivables/payables for realized transactions, delivered and unbilled revenues, and mark-to-market gains/losses (pursuant to contract terms). Exposures are offset according to legally enforceable netting arrangements. Amounts are presented before those reserves that are determined on a portfolio basis. (See "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Western United States Wholesale Power Market" for discussion of the reserves.)

(c) The Credit Collateral reflects the face amount of cash deposits, letters of credit and performance bonds received from counterparties.

87

PNM hedges certain portions of natural gas supply contracts in order to protect its retail customers from adverse price fluctuations in the natural gas market. The financial impact of all hedge gains and losses, including the related costs of the program, is recoverable through the purchased gas adjustment clause. As a result, earnings are not affected by gains and losses generated by these instruments.

Interest Rate Risk

As of December 31, 2002, the Company has an investment portfolio of fixed-rate government obligations and corporate securities, which were subject to the risk of loss, associated with movements in market interest rates. For accounting purposes, the portfolio is classified as available-for-sale and is marked-to-market. As a result, unrealized losses resulting from interest rate increases are recorded as a component of comprehensive income. If interest rates were to rise 50 basis points from their levels at December 31, 2002, the fair value of these instruments would decline by 0.7% or $0.6 million. In addition, because of this interest rate sensitivity, early or unplanned redemption of these investments in a period of increasing interest rates would subject the Company to risk of a realized loss of principal as the fair market value of these investments would be less than their carrying value. The Company employs investment managers to mitigate this risk. As part of its investing strategies, the Company has diversified its portfolio with investments of varying maturity and obligors and limits credit exposure to high investment grade quality investments.

PNM has long-term debt which subjects it to the risk of loss associated with movements in market interest rates. All of the Company's long-term debt is fixed-rate debt, and therefore, does not expose the Company's earnings to a risk of loss due to adverse changes in market interest rates. However, the fair value of these debts instruments would increase by approximately 4.05% or $38.8 million if interest rates were to decline by 50 basis points from their levels at December 31, 2002. As of December 31, 2002, the fair value of PNM's long-term debt was $960 million as compared to a book-value of $954 million. In general, an increase in fair value would impact earnings and cash flows if PNM were to re-acquire all or a portion of its debt instruments in the open market prior to their maturity. Certain issuances of the debt have call dates in December 2002 and August 2003. To hedge against the risk of rising interest rates and their impact on the economics of calling the debt, PNM has entered into forward starting interest rate swaps in 2001 and 2002. These forward interest rate swaps effectively lock-in interest rates for the notional amount of the debt that is callable at a rate of approximately 4.95% plus an adjustment for PNM's and the industry's credit ratings. At December 31, 2002, the fair market value of these derivative financial instruments was approximately $18.4 million unfavorable to the Company.

PNM contributed $6.1 million in 2001 to a trust established to fund decommissioning costs for PVNGS. In January 2002, PNM contributed $23.5 million for plan year 2001 to the trust for the Company's pension plan, and other post retirement benefits. Additional contributions were made in September 2002 for $1.1 million and in December 2002 for $1.5 million for the 2002 plan year. The securities held by the trusts had an estimated fair value of $63.2 million as of December 31, 2002, of which approximately 27% were fixed-rate debt securities that subject the Company to risk of loss of fair value with movements in market interest rates. If rates were to increase by 50 basis points from their levels at December 31, 2002, the decrease in the fair value of the securities would be 3.2% or $4.3 million. PNM does not currently recover or return through rates any

88

losses or gains on these securities; therefore, the Company is at risk for shortfalls in its funding of its obligations due to investment losses. However, the Company does not believe that long-term market returns over the period of funding will be less than required for the Company to meet its obligations. (For further information, see "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Pension and Other Post-Retirement Benefits.")

Equity Market Risk

As discussed above under Interest Rate Risk, PNM contributes to trusts established to fund its share of the decommissioning costs of PVNGS and pension and other post-retirement benefits. The trusts hold certain equity securities as of December 31, 2002. These equity securities also expose the Company to losses in fair value. Approximately 65% of the securities held by the various trusts were equity securities as of December 31, 2002. Similar to the debt securities held for funding decommissioning and certain pension and other post-retirement costs, PNM does not recover or earn a return on through rates, any losses or gains on these equity securities. (For further information, see "Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations - Pension and Other Post-Retirement Benefits.")

In 2001, the Company implemented an enhanced cash management strategy using derivative instruments based on the Standard & Poor's 100, S&P 500, and Nasdaq composite indices. The strategy is designed to capitalize on high market volatility or benefit from market direction. An investment manager is utilized to execute the program. The program is carefully managed by the RMC and has VAR and stop-loss limits established. Trades are typically closed-out before the end of a reporting period and within the same day of execution. There were no open positions as of December 31, 2002.

89

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA

INDEX

                                                                          Page
                                                                          ----

Management's Responsibility for Financial Statements...................    F-1
Report of Independent Auditor (PNM Resources, Inc.)....................    F-3
Report of Independent Auditor (Public Service Company of New Mexico)...    F-4
Financial Statements:
   PNM Resources, Inc. and Subsidiaries
       Consolidated Statements of Earnings.............................    F-5
       Consolidated Statements of Retained Earnings....................    F-6
       Consolidated Balance Sheets.....................................    F-7
       Consolidated Statements of Cash Flows...........................    F-9
       Consolidated Statements of Capitalization.......................   F-10
       Consolidated Statements of Comprehensive Income/(Loss)..........   F-11
   Public Service Company of New Mexico
       Consolidated Statements of Earnings.............................   F-12
       Consolidated Statements of Retained Earnings....................   F-13
       Consolidated Balance Sheets.....................................   F-14
       Consolidated Statements of Cash Flows...........................   F-16
       Consolidated Statements of Capitalization.......................   F-17
       Consolidated Statements of Comprehensive Income/(Loss)..........   F-18
   Notes to Consolidated Financial Statements..........................   F-19
Supplementary Data:
   Quarterly Operating Results.........................................   F-65
   Comparative Operating Statistics....................................   F-67
   Independent Auditors' Report........................................   F-68
   Schedule I Condensed Financial Information of Parent Company........   F-69
   Schedule II Valuation and Qualifying Accounts.......................   F-72

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,

F-1

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.

F-2

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.

DELOITTE & TOUCHE LLP

Omaha, Nebraska
February 11, 2003

F-3

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.

DELOITTE & TOUCHE LLP

Omaha, Nebraska
February 11, 2003

F-4

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.....................................................   $ 895,474     $1,952,861     $1,289,192
  Gas..........................................................     272,118        385,418        319,924
  Unregulated businesses.......................................       1,404          1,538          2,158
                                                                -------------  -------------  -------------
     Total operating revenues..................................   1,168,996      2,339,817      1,611,274
                                                                -------------  -------------  -------------
Operating Expenses:
  Cost of energy sold..........................................     550,053      1,524,285        949,880
  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..................................   1,067,222      2,117,140      1,478,800
                                                                -------------  -------------  -------------
     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.

F-5

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.

F-6

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.

F-7

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.

F-8

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.

F-9

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.

F-10

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.

F-11

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............................................      $ 895,474        $1,952,861       $1,289,192
  Gas.................................................        272,118           385,418          319,924
  Unregulated businesses..............................              -             1,538            2,158
                                                        ---------------   ---------------  ---------------
     Total operating revenues.........................      1,167,592         2,339,817        1,611,274
                                                        ---------------   ---------------  ---------------
perating Expenses:
  Cost of energy sold.................................        549,243         1,524,285          949,880
  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.........................      1,058,937         2,117,140        1,478,800
                                                        ---------------   ---------------  ---------------
     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.

F-12

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.

F-13

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.

F-14

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.

F-14

PUBLIC SERVICE COMPANY OF NEW MEXICO AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS

                                                                              Year Ended December 31,
                                                                     ----------------------------------------
                                                                       2002          2001          2000
                                                                     ------------  ------------  ------------
                                                                                  (In thousands)
Cash Flows From Operating Activities:
  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.

F-15

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.

F-17

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.

F-18

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. 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").

F-19

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.

F-20

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.

Inventory

Inventory consists principally of materials and supplies, natural gas held in storage for eventual resale, and coal held for use in electric generation.

F-21

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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.

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

F-22

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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 Generation and Marketing Operations record operating revenues to the Utility Operations and 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. Generation and Marketing Operations transactions that are net settled, are recorded gross in operating revenues and fuel and purchased power expense.

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 Generation and Marketing 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.

F-23

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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.

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.

F-24

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 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).

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).

F-25

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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
                                            ==========  ===========  ===========

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.

F-26

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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

As it currently operates, the Company's principal business segments are Utility Operations, which include Electric Services ("Electric") and Gas Services ("Gas"), Generation and Marketing Operations ("Generation and Marketing") and Unregulated Operations ("Unregulated"). Electric consists of two major business lines that include distribution and transmission. The transmission business line does not meet the definition of a segment due to its immateriality and is combined with the distribution business line for disclosure purposes.

UTILITY OPERATIONS

Electric

PNM provides retail electric service, regulated by the PRC, to a large area of north central New Mexico, including the cities of Albuquerque and Santa Fe, and certain other areas of New Mexico. PNM owns or leases 2,890 circuit miles of transmission lines, interconnected with other utilities in New Mexico and south and east into Texas, west into Arizona, and north into Colorado and Utah.

Electric exclusively acquires its electricity sold to retail customers from Generation and Marketing. Intersegment purchases from Generation and Marketing are priced using internally developed transfer pricing and are not based on market rates. Customer rates for electric service are set by the PRC based on the recovery of the cost of power delivery and production that includes certain generation assets that are part of Generation and Marketing plus a rate of return.

Gas

PNM's gas operations distribute natural gas to most of the major communities in New Mexico, including Albuquerque and Santa Fe. PNM's customer base includes both sales-service customers and transportation-service customers.

F-27

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

Customer rates for gas service are set by the PRC based on the recovery of the cost of delivering gas plus a rate of return, with the cost of gas procured for customers being passed through to customers through a purchased gas adjustment clause ("PGAC").

In 2000 and the first quarter of 2001, Generation and Marketing procured its gas fuel supply from Gas. Beginning with the second quarter of 2001, Generation and Marketing began procuring its gas supply independently of Gas and contracted with Gas for transportation services only.

GENERATION AND MARKETING OPERATIONS

Generation and Marketing serves four principal markets. These include sales to PNM's Utility Operations to cover retail electric demand, sales to firm-requirement wholesale customers, other contracted sales to third parties for a specified amount of capacity (measured in megawatts-MW) or energy (measured in megawatt hours-MWh) over a given period of time and energy sales made on an hourly basis at fluctuating, spot-market rates. In addition to generation capacity, PNM purchases power in the open market. As of December 31, 2002, the total net generation capacity of facilities owned or leased by PNM was 1,742 MW, including a 132 MW power purchase contract accounted for as an operating lease.

UNREGULATED AND OTHER

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. Unregulated also includes immaterial corporate activities and eliminations. The immaterial corporate activities were assumed by the Holding Company on December 31, 2001. Avistar was transferred by a way of a dividend to the Holding Company by its subsidiary, PNM.

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

F-28

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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.

Summarized financial information by business segment for 2002, 2001 and 2000 is as follows:

                                             Utility
                                  ------------------------------    Generation   Unregulated
                                  Electric      Gas       Total    and Marketing  and Other   Consolidated
                                  --------  ---------  ---------   ------------- -----------  ------------
                                                            (In thousands)
Twelve Months Ended:
--------------------------
2002:
Operating revenues:
   External customers............. 570,089   272,118     842,207      325,385        1,404      1,168,996
   Intersegment revenues..........     707         -         707      348,935     (349,642)             -
Depreciation and amortization.....  34,025    20,964      54,989       43,837        3,583        102,409
Interest income...................     436       436         872        1,995       42,087         44,954
Interest charges..................  23,640    13,546      37,186       16,625        7,601         61,412
Operating income (loss)...........  60,449    18,652      79,101       24,737      (2,064)        101,774
Income tax expense................  21,731     4,351      26,082        4,596        2,353         33,031
Segment net income................  33,163     6,640      39,803        7,013       17,456         64,272

Total assets...................... 761,694   505,692   1,267,386    1,124,387      635,134      3,026,907
Gross property additions..........  56,698    46,676     103,374      116,447       20,404        240,225

Twelve Months Ended:
--------------------------
2001:
Operating revenues:
   External customers............. 559,226   385,418      944,644   1,393,635        1,538      2,339,817
   Intersegment revenues..........     707         -          707     341,608     (342,315)             -
Depreciation and amortization.....  32,666    21,465       54,131      42,766           39         96,936
Interest income...................   1,626       596        2,222       3,215       43,304         48,741
Interest charges..................  19,868    11,807       31,675      28,282        4,883         64,840
Operating income (loss)...........  57,417    17,730       75,147     150,565       (3,035)       222,677
Income tax expense (benefit)......  23,679     3,469       27,148      73,525      (19,610)        81,063
Segment net income (loss).........  36,130     5,498       41,628     112,194       (3,389)       150,433

Total assets...................... 749,948   469,410    1,219,358   1,430,917      263,513      2,913,788
Gross property additions..........  74,316    48,978      123,294     126,605       14,945        264,844

F-29

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
                                  ------------------------------    Generation   Unregulated
                                  Electric      Gas       Total    and Marketing  and Other   Consolidated
                                  --------  ---------  ---------   ------------- -----------  ------------
                                                            (In thousands)
Twelve Months Ended:
--------------------------
2000:
Operating revenues:
   External customers.............  538,758   319,924     858,682     750,434        2,158     1,611,274
   Intersegment revenues..........      707         -         707     324,744     (325,451)            -
Depreciation and amortization.....   31,480    19,994      51,474      41,559           26        93,059
Interest income...................    1,158         9       1,167       1,708       45,820        48,695
Interest charges..................   17,771    11,089      28,860      37,058         (476)       65,442
Operating income (loss)...........   56,351    19,104      75,455      78,451      (21,432)      132,474
Income tax expense................   27,419     7,588      35,007      28,337       11,002        74,346
Segment net income................   38,999    11,208      50,207      49,372        1,367       100,946
Unaudited:
Total assets......................  698,979   516,430   1,215,409   1,400,910      277,914     2,894,233
Gross property additions..........   51,815    40,418      92,233      53,025        1,620       146,878

(Intentionally left blank)

F-30

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.

F-31

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 Generation and Marketing 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 and Marketing Operations 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 Global Electric Agreement" for further developments.)

F-32

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.

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.

F-33

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 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 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.

F-34

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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.

F-35

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.

F-36

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
                                      ============== =============  ============= ============

F-37

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.

F-38

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.

Generation and Marketing

Commencing in 2000, the Company's Generation and Marketing 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 Generation and Marketing 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.

F-39

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 Generation and Marketing 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 Generation and Marketing 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 current low interest rates, PNM entered into five forward starting interest rate

F-40

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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)

F-41

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)

F-42

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%
                                                       =============  ============   ============

F-43

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.

F-44

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)

F-45

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)
                                                      ============  ============  ============

F-46

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
                                                          =============  ===============  =============

F-47

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. The total number of shares of common stock subject to all awards under the PEP

F-48

PNM RESOURCES, INC. AND SUBSIDIARIES AND
PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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)

F-49

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
                            ==============                                    ===============

F-50

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.

F-51

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.

F-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

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.

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.

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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

The natural gas used as fuel by Generation and Marketing was delivered by Gas. In the second quarter of 2001, Generation and Marketing 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.

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

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PUBLIC SERVICE COMPANY OF NEW MEXICO

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Continued)

December 31, 2002, 2001 and 2000

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.

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).

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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

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 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.

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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

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.

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.

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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

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.

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.

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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

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.

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).

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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

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.

(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.

(Intentionally left blank)

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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

(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
                                                     =============  ============   =============

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
                                                     =============  ============   =============

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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

(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.

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.

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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

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.

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.

F-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

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.

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 ("SFAS 133") "Accounting for Derivative Instruments and Hedging Activities". 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 adjustment in the period of adoption. This transition provision will be effective for the first quarter of 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 is reviewing its energy contract portfolio to determine whether its contracts meet the definition of trading activities under EITF 02-3 which should be presented on a net margin basis. The Company will reclassify prior periods to a net margin basis for those contracts previously accounted for under EITF 98-10 in the first quarter of 2003. The Company does not expect to 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 of Company's marketing activities meet the definitions of trading activities as prescribed by EITF 02-3.

F-64

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.....................  $ 313,996   $ 264,569       $ 289,440     $ 300,991
  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.....................  $ 736,530   $ 666,091       $ 621,895     $ 315,301
  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.

F-65

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
  Intersegment revenues....................          707          707          707         707         707
  Miscellaneous electric revenues..........       28,164       31,707       20,093      18,345      19,151
                                             ------------ ------------ ------------ ----------- -----------
    Total electric revenues................    $ 570,796    $ 559,933    $ 539,465   $ 541,575   $ 556,275
                                             ------------ ------------ ------------ ----------- -----------
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............    $ 842,914    $ 945,351    $ 859,389   $ 778,286   $ 812,250
                                             ============ ============ ============ =========== ===========

F-66

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
                                            ============ =============  ============ ============ ============
Generation and Marketing Operations Sales:
Energy Sales--KWh (in thousands):
  Firm-requirements wholesale.............      581,428       616,703       330,003      179,249      278,615
  Other contracted off-system.............    4,192,788     6,900,589     7,315,679    6,196,499    4,033,931
  Economy energy sales....................    4,675,939     5,059,808     4,706,446    4,795,873    4,469,769
                                            ------------ -------------  ------------ ------------ ------------
    Total sales to ultimate customers.....    9,450,155    12,577,100    12,352,128   11,171,621    8,782,315
  Intersegment sales......................    7,406,506     7,255,297     7,088,943    6,803,583    6,739,874
                                            ------------ -------------  ------------ ------------ ------------
    Total energy sales....................   16,856,661    19,832,397    19,441,071   17,975,204   15,522,189
                                            ============ =============  ============ ============ ============
Revenues (in thousands):
  Firm-requirements wholesale.............   $   25,973     $  24,754     $  15,540     $  7,046    $  10,708
  Other contracted off-system.............      135,322       879,824       364,278      226,773      142,115
  Economy energy sales....................      116,280       512,209       368,374      131,549      122,156
                                            ------------ -------------  ------------ ------------ ------------
    Total revenues to ultimate customers..      277,575     1,416,787       748,192      365,368      274,979
  Intersegment revenues...................      348,935       341,608       324,744      318,872      362,722
  Miscellaneous electric revenues.........       47,810       (23,152)        2,242        5,741        4,657
                                            ------------ -------------  ------------ ------------ ------------
    Total generation revenues.............   $  674,320    $1,735,243    $1,075,178    $ 689,981    $ 642,358
                                            ============ =============  ============ ============ ============
Customers at Year End:
Generation                                           76            79            81           83           83
                                            ============ =============  ============ ============ ============
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

F-67

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

F-68

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
                                                               =============   ==============

F-69

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
                                                      ==============

F-70

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        $      -
                                                                           ===============  ==============

F-71

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").

F-72

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND
FINANCIAL DISCLOSURE

Information has been previously reported as defined in SEC Rule 12b-2.

PART III

ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE COMPANY

Reference is hereby made to "Election of Directors" in the Company's Proxy Statement relating to the annual meeting of stockholders to be held on May 13, 2003 (the "2003 Proxy Statement"), to PART I, SUPPLEMENTAL ITEM - "EXECUTIVE OFFICERS OF THE COMPANY" and "Other Matters" - "Section 16(a) Beneficial Ownership Reporting Compliance" in the 2003 Proxy Statement.

ITEM 11. EXECUTIVE COMPENSATION

Reference is hereby made to "Executive Compensation" in the 2003 Proxy Statement.

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
AND RELATED STOCKHOLDER MATTERS

Reference is hereby made to "Voting Information", "Election of Directors", "Stock Ownership of Certain Executive Officers" and "Equity Compensation Plan Information" in the 2003 Proxy Statement.

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS

Reference is hereby made to the 2003 Proxy Statement for such disclosure, if any, as may be required by this item.

ITEM 14. CONTROLS AND PROCEDURES

(a) Evaluation of disclosure controls and procedures.

The Company's principal executive officer and principal financial officer have concluded that the Company's disclosure controls and procedures, based on their evaluation on March 5, 2003 of these disclosure controls and procedures, are effective to ensure that material information relating to the Company, including its consolidated subsidiaries, was made known to them by others within those entities, particularly during the period in which the periodic reports are being prepared.

(b) Changes in internal controls.

None.

E-1

PART IV

ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS
ON FORM 8-K

(a) - 1. See Index to Financial Statements under Item 8.
(a) - 2. Financial Statement Schedules for the years 2001, 2000, and 1999 are omitted for the reason that they are not required or the information is otherwise supplied.

(a) - 3-A. Exhibits Filed:

Exhibit No.                               Description
-----------                               -----------

3.2              Bylaws of PNM Resources, with all amendments to and including
                 February 18, 2003

10.23.5**        Fifth Amendment dated November 27, 2002 to Restated and Amended
                 PNM Accelerated  Management Performance Plan

10.25.1**        Amendment dated November 27, 2002 to the Second Restated and
                 Amended PNM Executive Medical Plan

10.43.1**        2002 Officer Incentive Plan

10.43.2**        2003 Officer Incentive Plan

10.45.4**        Fourth Amendment dated November 27, 2002 to the Service Bonus
                 Plan

10.48.2**        Second Amendment dated November 27, 2002 to the PNM OBRA '93
                 Retirement Plan

10.50.1**        First Amendment dated December 7, 1998, Second Amendment dated
                 August 7, 1999 and Third Amendment dated November 22, 2002 to
                 the PNM Section 415 Plan

10.51.1**        First Amendment dated November 27, 2002 to the PNM First
                 Restated and Amended Executive Retention Plan

10.52**          PNM Resources, Inc. Executive Spending Account Plan executed
                 November 27, 2002

10.72            Credit Agreement dated as of December 19, 2002 among PNM, the
                 Lenders identified therein, Bank of America, N.A. as
                 administrative agent, Wachovia Bank, as syndication agent, and
                 Fleet National Bank, as documentation agent

E-2

Exhibit No.                               Description
-----------                               -----------

10.75**          Second Restated and Amended PNM Resources, Inc. Executive
                 Savings Plan dated January 1, 2003

10.86            Stipulation in the matter of PNM's transition plan, Utility
                 Case 3137, dated October 10, 2002, as amended by Amendment to
                 Stipulated Agreement dated October 18, 2002

10.87**          Long Term Care Insurance Plan effective January 1, 2003

10.88**          Executive Long Term Disability effective January 1, 2003

23.1             Consent of Deloitte & Touche LLP for PNM Resources, Inc.

23.2             Consent of Deloitte & Touche LLP for Public Service Company of
                 New Mexico.

99.1             Chief Executive Officer Certification Pursuant to Section 906
                 of the Sarbanes-Oxley Act of 2002.

99.2             Chief Financial Officer (Max H. Maerki, through December 31,
                 2002) Certification Pursuant to Section 906 of the
                 Sarbanes-Oxley Act of 2002.

99.3             Chief Financial Officer (John R. Loyack, beginning January 1,
                 2003) Certification Pursuant to Section 906 of the
                 Sarbanes-Oxley Act of 2002.

(a) - 3-B. Exhibits Incorporated By Reference:

In addition to those Exhibits shown above, PNM and PNM Resources hereby incorporate the following Exhibits pursuant to Exchange Act Rule 12b-32 and Regulation S-K section 10, paragraph (d) by reference to the filings set forth below:

Exhibit No.         Description of Exhibit                   Filed as Exhibit:             File No:
----------          ----------------------                   -----------------             --------

Articles of Incorporation and By-laws

3.1.1          Restated Articles of Incorporation of        4-(b) to PNM's                 2-99990
               PNM, as amended through                      Registration Statement
               May 10, 1985

3.2            Bylaws of PNM Resources, Inc.                4.2 of Post-Effective         333-10993
               with all Amendments to and                   Amendment No. 1 to
               including April 17, 2001                     PNM Resources Form
                                                            S-3 Registration
                                                            Statement filed
                                                            October 4, 2001

E-3

Exhibit No.         Description of Exhibit                   Filed as Exhibit:             File No:
----------          ----------------------                   -----------------             --------

Instruments Defining the Rights of Security Holders, Including Indentures

3.2.1          By-laws of PNM with All                        3.2 to PNM's Annual          1-6986
               Amendments to and including                    Report on Form 10-K
               February 8, 2000                               for the fiscal year ended
                                                              December 31, 2000

4.1            Indenture of Mortgage and Deed of              4-(d) to PNM's               2-99990
               Trust dated as of June 1, 1947, between        Registration Statement
               PNM and The Bank of New York                   No. 2-99990
               (formerly Irving Trust Company), as
               Trustee, together with the Ninth
               Supplemental Indenture dated as of
               January 1, 1967, the Twelfth
               Supplemental Indenture dated as of
               September 15, 1971, the Fourteenth
               Supplemental Indenture dated as of
               December 1, 1974 and the Twenty-
               Second Supplemental Indenture dated
               as of October 1, 1979 thereto relating to
               First Mortgage Bonds of PNM

4.3            Fifty-third Supplemental Indenture,            4.3 to PNM's Quarterly       1-6986
               dated as of March 11, 1998,                    Report on Form 10-Q for
               supplemental to Indenture of Mortgage          the quarter ended March
               and Deed of Trust, dated as of June 1,         31, 1998.
               1947, between PNM and The Bank of
               New York(formerly Irving Trust
               Company), as trustee.

4.4            Indenture (for Senior Notes), dated            4.4 to PNM's Quarterly       1-6986
               as of March 11, 1998, between PNM              Report on Form 10-Q
               and The Chase Manhattan Bank, as               for the quarter ended
               Trustee.                                       March 31, 1998.

4.5            First Supplemental Indenture, dated            4.5 to PNM's Quarterly       1-6986
               as of March 11, 1998, supplemental to          Report on Form 10-Q for
               Indenture, dated as of March 11, 1998,         the quarter ended March
               Between PNM and The Chase                      31, 1998.
               Manhattan Bank, as Trustee.

4.6            Second Supplemental Indenture, dated           4.6 to PNM's Quarterly       1-6986
               as of March 11, 1998, supplemental to          Report on Form 10-Q for
               Indenture, dated as of March 11, 1998,         the quarter ended March
               Between PNM and The Chase                      31, 1998.
               Manhattan Bank, as Trustee.

4.6.1          Third Supplemental Indenture, dated            4.6.1 to PNM's Annual        1-6986
               as of October 1, 1999 to Indenture             Report on Form 10-K
               dated as of March 11, 1998, between            for the fiscal year ended
               PNM and The Chase Manhattan                    December 31, 1999.
               Bank, as Trustee

E-4

Exhibit No.         Description of Exhibit                   Filed as Exhibit:             File No:
----------          ----------------------                   -----------------             --------

4.7            Indenture (for Senior Notes), dated            4.1 to PNM's                 3-53367
               as of August 1, 1998, between PNM              Registration Statement
               and The Chase Manhattan Bank, as               No. 33-53367
               Trustee.

Material Contracts

10.1           Supplemental Indenture of Lease                4-D to PNM's                 2-26116
               dated as of July 19, 1966 between              Registration Statement
               PNM and other participants in the              No. 2-26116
               Four Corners Project and the Navajo
               Indian Tribal Council.

10.1.1         Amendment and Supplement No. 1                 10.1.1 to PNM's              1-6986
               to Supplemental and Additional Indenture       Annual Report on
               of Lease dated April 25,                       Form 10-K for fiscal
               1985 between the Navajo Tribe of               year ended December
               Indians and Arizona Public Service             31, 1995.
               Company, El Paso Electric Company, Public
               Service Company of New Mexico, Salt River
               Project Agricultural Improvement and Power
               District, Southern California Edison Company,
               and Tucson Electric Power Company (refiled).

10.2           Fuel Agreement, as supplemented,               4-H to PNM's                 2-35042
               dated as of September 1, 1966 between          Registration Statement
               Utah Construction & Mining Co. and             No. 2-35042
               the participants in the Four Corners
               Project including PNM.

10.3           Fourth Supplement to Four Corners              10.3 to PNM's Annual         1-6986
               Fuel Agreement No. 2 effective as of           Report on Form 10-K
               January 1, 1981, between Utah                  for fiscal year ended
               International Inc. and the participants        December 31, 1991.
               in the Four Corners Project, including PNM.

10.4           Contract between the United States             5-L to PNM's                 2-41010
               and PNM dated April 11, 1968, for              Registration Statement
               furnishing water.                              No. 2-41010

10.4.1         Amendatory Contract between the                5-R to PNM's                 2-60021
               United States and PNM dated                    Registration Statement
               September 29, 1977, for furnishing             No. 2-60021
               water.

10.5           Water Supply Agreement between                 10.5 to PNM's Quarterly      1-6986
               the Jicarilla Apache Tribe and Public          Report of Form 10-Q for
               Service Company of New Mexico,                 the quarter ended
               dated July 20, 2000                            September 30, 2001

E-5

Exhibit No.         Description of Exhibit                   Filed as Exhibit:                 File No:
----------          ----------------------                   -----------------                 --------

10.8           Arizona Nuclear Power Project                 5-T to PNM's                      2-50338
               Participation Agreement among PNM             Registration Statement
               and Arizona Public Service Company,           No. 2-50338
               Salt River Project Agricultural
               Improvement and Power District,
               Tucson Gas & Electric Company and
               El Paso Electric Company, dated
               August 23, 1973.

10.8.1         Amendments No. 1 through No. 6 to             10.8.1 to PNM's Annual            1-6986
               Arizona Nuclear Power Project                 Report on Form 10-K
               Participation Agreement.                      for fiscal year ended
                                                             December 31, 1991.

10.8.2         Amendment No. 7 effective April 1,            10.8.2 to PNM's Annual            1-6986
               1982, to the Arizona Nuclear Power            Report on Form 10-K
               Project Participation Agreement                for fiscal year ended
               (refiled).                                    December 31, 1991.

10.8.3         Amendment No. 8 effective September           10.58 to PNM's Annual             1-6986
               12, 1983, to the Arizona Nuclear Power        Report on Form 10-K
               Project Participation Agreement               for fiscal year ended
               (refiled).                                    December 31, 1993.

10.8.4         Amendment No. 9 to Arizona Nuclear            10.8.4 to PNM's Annual            1-6986
               Power Project Participation Agreement         Report of the Registrant
               dated as of June 12, 1984 (refiled).          on Form 10-K for fiscal
                                                             year ended December
                                                             31, 1994.

10.8.5         Amendment No. 10 dated as of                  10.8.5 to PNM's Annual            1-6986
               November 21, 1985 and Amendment               Report of the Registrant
               No. 11 dated as of June 13, 1986 and          on Form 10-K for fiscal
               effective January 10, 1987 to Arizona         year ended December
               Nuclear Power Project Participation           31, 1994.
               Agreement (refiled).

10.8.7         Amendment No. 12 to Arizona Nuclear           19.1 to PNM's Quarterly Report    1-6986
               Power Project Participation Agreement         on Form 10-Q for the quarter
               dated June 14, 1988, and effective            ended September 30, 1990.
               August 5, 1988.

10.8.8         Amendment No. 13 to the Arizona               10.8.10 to PNM's Annual Report    1-6986
               Nuclear Power Project Participation           on Form 10-K for the fiscal
               Agreement dated April 4, 1990, and            year ended December 31, 1990.
               effective June 15, 1991.

10.8.9         Amendment No. 14 to the Arizona Nuclear       10.8.9 to PNM's Annual Report
               Power Project Participation Agreement         on Form 10-K for the fiscal
               effective June 20, 2000.                      year ended December 31, 2000.

E-6

Exhibit No.         Description of Exhibit                   Filed as Exhibit:                  File No:
----------          ----------------------                   -----------------                  --------
10.9           Coal Sales Agreement executed August 18,      10.9 to PNM's Annual Report        1-6986
               1980 among San Juan Coal Company, PNM         for fiscal year ended December
               and Tucson Electric Power Company,            31, 1991.
               together with Amendments No. One, Two,
               Four, and Six thereto.

10.9.1         Amendment No. Three to Coal Sales             10.9.1 to PNM's Annual Report      1-6986
               Agreement dated April 30, 1984 among San      on Form 10-K for fiscal year
               Juan Coal Company, PNM and Tucson Electric    ended December 31, 1994
               Power Company.                                (confidentiality treatment
                                                             was requested at the  time of
                                                             filing the Annual Report of
                                                             the Registrant on Form
                                                             10-K for fiscal year ended
                                                             December 31, 1984; exhibit
                                                             was not filed therewith
                                                             based on the same
                                                             confidentiality request).

10.9.2         Amendment No. Five to Coal Sales              10.9.2 to PNM's Annual Report      1-6986
               Agreement dated May 29, 1990 among            on Form 10-K for fiscal year
               San Juan Coal Company, PNM and Tucson         ended December 31, 1991
               Electric Power Company.                       (confidentiality treatment
                                                             was requested as to
                                                             portions of this exhibit,
                                                             and such portions were
                                                             omitted from the exhibit
                                                             filed and were filed
                                                             separately with the
                                                             Securities and Exchange
                                                             Commission).

10.9.3         Amendment No. Seven to Coal Sales             19.3 to PNM's Quarterly Report     1-6986
               Agreement, dated as of July 27,               on Form 10-Q for the quarter
               1992 among San Juan Coal Company,             ended September 30, 1992
               PNM and Tucson Electric Power Company.        (confidentiality treatment
                                                             was requested as to
                                                             portions of this exhibit,
                                                             and such portions were
                                                             omitted from the exhibit
                                                             filed and were filed
                                                             separately with the
                                                             Securities and Exchange
                                                             Commission).

E-7

Exhibit No.         Description of Exhibit                   Filed as Exhibit:                  File No:
----------          ----------------------                   -----------------                  --------
10.9.4         First Supplement to Coal Sales Agreement,     19.4 to PNM's Quarterly Report     1-6986
               dated July 27, 1992 among San Juan Coal       on Form 10-Q for the quarter
               Company, PNM and Tucson Electric Power        ended September 30, 1992
               Company.                                      (confidentiality treatment
                                                             was requested as to
                                                             portions of this exhibit,
                                                             and such portions were
                                                             omitted from the exhibit
                                                             filed and were filed
                                                             separately with the
                                                             Securities and Exchange
                                                             Commission).

10.9.5         Amendment No. Eight to Coal Sales             10.9.5 to PNM's Annual Report      1-6986
               Agreement, dated as of September 1, 1         on Form 10-K for fiscal year
               995, among San Juan Coal Company,             ended December 31, 1995.
               PNM and Tucson Electric Power  Company.

10.9.6         Amendment No. Nine to Coal Sales              10.9.6 to PNM's Annual Report      1-6986
               Agreement, dated as of December 31, 1995,     of the Registrant on Form 10-K
               among San Juan Coal Company,                  for fiscal year ended December
               PNM and Tucson Electric Power Company.        31, 1996.

10.9.8         Amendment No. 11 to Coal Sales Agreement,     10.9.8 to PNM's Quarterly
               Adated ugust 31, 2001 among San Juan          report on Form 10-Q for the
               Coal Company, PNM and Tucson Electric         quarter ended September 30,
               Power Company                                 2001. (Confidential treatment
                                                             was requested as to
                                                             portions of this exhibit,
                                                             and such portions were
                                                             omitted from the exhibit
                                                             filed and were filed
                                                             separately with the
                                                             Securities and Exchange
                                                             Commission).

10.11          San Juan Unit 4 Early Purchase and            10.11 to PNM's Quarterly           1-6986
               Participation Agreement dated as of           Report on Form 10-Q for the
               September 26, 1983 between PNM and            quarter ended March 31, 1994.
               M-S-R Public Power Agency, and  dated
               December 31, Modification No. 2 to the
               San Juan Project Agreements 1983 (refiled).

E-8

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                  File No:
----------          ----------------------                            -----------------                  --------
10.11.1        Amendment No. 1 to the Early Purchase and              10.11.1 to PNM's Annual            1-6986
               Participation Agreement between Public                 Report on Form 10-K
               Service Company of New Mexico and M-S-R                for fiscal year
               Public Power Agency, executed as of December           ended December 31, 1997.
               16, 1987, for San Juan Unit 4 (refiled).


10.11.3        Amendment No. 3 to the San Juan Unit 4                 10.11.3 to PNM's Annual            1-6986
               Early Purchase and Participation Agreement             Report on Form 10-K
               between Public Service  Company of New                 for fiscal year
               Mexico and M-S-R Public Power Agency,                  ended December 31, 1999.
               dated as of October 27, 1999.

10.12          Amended and Restated San Juan Unit 4                   10.12 to PNM's Annual Report       1-6986
               Purchase and Participation Agreement                   on Form 10-K for fiscal year
               dated as of December 28, 1984 between                  ended December 31, 1994.
               PNM and the Incorporated
               County of Los Alamos (refiled).

10.12.1        Amendment No. 1 to the Amended and                     10.12.1 to PNM's Annual Report     1-6986
               Restated San Juan  Unit 4 Purchase and                 Form 10-K for fiscal year
               Participation Agreement between  Public                ended December 31, 1999.
               Service Company of New Mexico and M-S-R
               Public Power Agency, dated as of October
               27, 1999.

10.13          Amendment No. 2 to the San Juan Unit 4 Purchase        10.13 to PNM's Annual Report       1-6986
               Agreement and Participation Agreement between Public   on Form 10-K for fiscal year
               Service Company of New Mexico and The Incorporated     ended December 31, 1999.
               County of Los Alamos, New Mexico, dated October 27,
               1999.

10.14          Participation Agreement among PNM, Tucson Electric     10.14 to PNM's Annual Report       1-6986
               Power Company and certain financial institutions       on Form 10-K for fiscal year
               relating to the San Juan Coal Trust dated as of        ended December 31, 1992.
               December 31, 1981 (refiled).

10.16          Interconnection Agreement dated November 23, 1982,     10.16 to PNM's Annual Report       1-6986
               between PNM and Southwestern Public Service Company    on Form 10-K for fiscal year
               (refiled).                                             ended December 31, 1992.

10.18*         Facility Lease dated as of December 16, 1985 between   10.18 to PNM's Annual Report       1-6986
               The First National Bank of Boston, as Owner Trustee,   on Form 10-K for fiscal year
               and Public Service Company of New Mexico together      ended December 31, 1995.
               with Amendments No. 1, 2 and 3 thereto (refiled).

10.18.4*       Amendment No. 4 dated as of March 8, 1995, to          10.18.4  to the PNM's Quarter      1-6986
               Facility Lease between Public Service Company of New   Report on Form
               Mexico and the First National Bank of Boston, dated    10-Q for the quarter ended
               as of December 16, 1985.                               March 31, 1995.

E-9

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                  File No:
----------          ----------------------                            -----------------                  --------
10.19          Facility Lease dated as of July 31, 1986, between the  10.19 to PNM's Annual Report       1-6986
               First National Bank of Boston, as Owner Trustee, and   on Form 10-K for fiscal year
               Public Service Company of New Mexico together with     ended December 31, 1996.
               Amendments No. 1, 2 and 3 thereto (refiled).

10.20*         Facility Lease dated as of August 12, 1986, between    10.20 to PNM's Annual Report       1-6986
               The First National Bank of Boston, as Owner Trustee,   on Form 10-K for fiscal year
               and Public Service Company of New Mexico together      ended December 31, 1996.
               with Amendments No. 1 and 2 thereto (refiled).

10.20.2        Amendment No. 2 dated as of April 10, 1987 to          10.20.2 to PNM's Annual Report     1-6986
               Facility Lease dated as of August 12, 1986, as         on Form 10-K for fiscal year
               amended, between The First National Bank of Boston,    ended December 31, 1998.
               not in its individual capacity, but solely as Owner
               Trustee under a Trust Agreement, dated as of August
               12, 1986, with MFS Leasing Corp., Lessor and Public
               Service Company of New Mexico, Lessee (refiled)

10.20.3        Amendment No. 3 dated as of March 8, 1995, to          10.20.3  to PNM's Quarterly        1-6986
               Facility Lease between Public Service Company of New   Report on Form 10-Q dated
               Mexico and the First National Bank of Boston,          for the quarter ended March
               as of August 12, 1986.                                 31, 1995.

10.21          Facility Lease dated as of December 15, 1986,          10.21 to PNM's Annual Report on    1-6986
               between The First National Bank of Boston, as Owner    Form 10-K for fiscal year ended
               Trustee, and Public Service Company of New Mexico      December 31, 1996.
               (Unit 1 Transaction) together with Amendment No. 1
               thereto (refiled).

10.22          Facility Lease dated as of December 15, 1986,          10.22 to PNM's Annual Report of    1-6986
               between The First National Bank of Boston, as Owner    the Registrant on Form 10-K for
               Trustee, and Public Service Company of New Mexico      fiscal year ended December 31,
               Unit 2 Transaction) together with Amendment No. 1      1996.
               thereto (refiled).

10.23**        Restated and Amended Public Service Company of New     10.23 to PNM's Annual Report on    1-6986
               Mexico Accelerated Management Performance Plan         Form 10-K for fiscal year ended
               (1988) (August 16, 1988) (refiled).                    December 31, 1998.


10.23.1**      First Amendment to Restated and Amended Public         10.23.1 to PNM's Annual Report     1-6986
               Service Company of New Mexico Accelerated              on Form 10-K for fiscal year
               Management o Performance Plan (1988)                   ended December 31, 1998.
               (August 30, 1988) (refiled).

E-10

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                  File No:
----------          ----------------------                            -----------------                  --------
10.23.2**      Second Amendment to Restated and Amended Public        10.23.2 to PNM's Annual Report     1-6986
               Service Company of New Mexico Accelerated              on Form 10-K for fiscal year
               Management Performance Plan (1988)                     ended December 31, 1998.
               (December 29, 1989) (refiled).

10.23.4**      Fourth Amendment to the Restated and Amended Public    10.23.4 to PNM's Quarterly         1-6986
               Service Company of New Mexico Accelerated              on Form 10-Q for the
               Management Report  Performance Plan, as                quarter ended March 31, 1999.
               amended effective December 7, 1998

10.24**        Management Life Insurance Plan (July 1985) of the      10.24 to PNM's Annual Report on    1-6986
               Company (refiled).                                     Form 10-K for fiscal year ended
                                                                      December 31, 1995.

10.25.1**      Second Restated and Amended Public Service Company     10.25.1 to PNM's Annual Report     1-6986
               of New Mexico Executive Medical Plan as amended on     on Form 10-K for fiscal year
               ended December 28, 1995.                               December 31, 1997.

10.27          Amendment No. 2 dated as of April 10, 1987, to the     10.53 to PNM's Annual Report on    1-6986
               Facility Lease dated as of August 12, 1986, between    Form 10-K for fiscal year ended
               The First National Bank of Boston, as Owner Trustee,   December 31, 1987.
               and Public Service Company of New Mexico.  (Unit 2
               Transaction.) (This is an amendment to a Facility
               Lease which is substantially similar to the Facility
               Lease filed as Exhibit 28.1 to the Company's Current
               Report on Form 8-K dated August 18, 1986.)

10.32**        Supplemental Employee Retirement Agreements dated      10.32 to PNM's Annual Report on    1-6986
               August 4, 1989, Between Public Service Company of      Form 10-K for fiscal year ended
               New Mexico and John R. Ackerman and Max Maerki         December 31, 1999.
               (refiled).

10.32.1**      First Amendment to the Supplemental Employee           10.32.1 to PNM's Quarterly         1-6986
               Retirement Agreement for Max H. Maerki, as amended     Report on Form 10-Q for the
               effective August 10, 1998.                             quarter ended September 30, 1998.

10.32.2**      Second Amendment to the Supplemental Employee          10.32.2 to PNM's Quarterly         1-6986
               Retirement Agreement for Max H. Maerki, as             Report on Form 10-Q
               amended  for the effective December 7, 1998            quarter ended March 31, 1999.

E-11

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                  File No:
----------          ----------------------                            -----------------                  --------

10.32.3**      First Amendment to the Supplemental Employee          10.32.3 to PNM's Quarterly          1-6986
               Retirement Agreement for John T. Ackerman, as         Report on Form 10-Q for the
               amended effective December 7, 1998                    quarter ended March 31, 1999.

10.34          Settlement Agreement between Public Service Company   10.34 to PNM's Quarterly            1-6986
               of New Mexico and Creditors of Meadows Resources,     Report on Form 10-Q for
               Inc. dated November 2, 1989 (refiled).                quarter ended June 30, 2000.

10.34.1        First amendment dated April 24, 1992 to the           10.34.1 to PNM's Quarterly          1-6986
               Settlement Agreement dated November 2, 1989           Report on Form 10-Q for
               among  Public Service Company of New                  quarter ended June 30, 2000.
               Mexico, the lender  parties thereto
               and collateral agent (refiled).

10.35          Amendment dated April 11, 1991 among Public Service   19.1 to PNM's Quarterly             1-6986
               Company of New Mexico, certain banks and Chemical     Report on Form 10-Q for the
               Bank and Citibank, N.A., as agents for the banks.     quarter ended September 30,
                                                                     1991.

10.36          San Juan Unit 4 Purchase and Participation Agreement  19.2 to PNM's Quarterly             1-6986
               Public Service Company of New Mexico and the City of  Report on Form 10-Q for the
               Anaheim, California dated April 26, 1991.             quarter ended March 31, 1991.

10.36.1        Amendment No. 1 to the San Juan Unit 4 Purchase and   10.36.1 to Annual Report            1-6986
               Participation Agreement between Public Service        PNM's on Form 10-K for fiscal
               Company of New Mexico and The City of Anaheim,        year ended
               California, dated October 27, 1999                    December 31, 1999.

10.38          Restated and Amended San Juan Unit 4 Purchase and     10.2.1 to PNM's Quarterly           1-6986
               Participation Agreement between Public Service        Report on Form 10-Q for the
               Company of New Mexico and Utah Associated Municipal   quarter ended September 30,
               Power Systems.                                        1993.

10.38.1        Amendment No. 1 to the Restated and Amended San Juan  10.38.1 to PNM's Annual             1-6986
               Unit 4 Purchase And Participation Agreement between   Report on Form 10-K for
               Public Service Company of New Mexico And Utah         fiscal year ended December
               Associated Municipal Power Systems,                   31, 1999.
               dated October 27, 1999.

E-12

Exhibit No.         Description of Exhibit                             Filed as Exhibit:                  File No:
----------          ----------------------                             -----------------                  --------
10.40**         PNM Resources, Inc. Director Retainer Plan, dated      4.3 to PNM Resources, Inc.        333-03289
                December 31, 2001                                      Post-Effective Amendment No.
                                                                       1 to Form 8 Registration
                                                                       Statement filed December 31,
                                                                       2001

10.41           Waste Disposal Agreement, dated as of July 27, 1992    19.5 to PNM's Quarterly            1-6986
                among San Juan Coal Company, PNM and Tucson Electric   Report on Form 10-Q for the
                Power Company.                                         quarter ended September 30,
                                                                       1992 (confidentiality
                                                                       treatment was requested as to
                                                                       portions of this
                                                                       exhibit, and such portions
                                                                       were omitted from the exhibit
                                                                       and were filed separately
                                                                       with the Securities and Exchange
                                                                       Commission).

10.42           Stipulation in the matter of the application of Gas    10.42 to PNM's Annual Report       1-6986
                Company of New Mexico for an order authorizing         on Form 10-K for fiscal year
                recovery of MDL costs through Rate Rider Number 8.     ended December 31, 1992.

10.43           2001 Officer Incentive Plan effective January 1, 2001  10.43 to PNM's Annual Report
                                                                       on Form 10-K for the fiscal
                                                                       year ended December 31, 2000

10.44.2**       Second Restated and Amended Non-Union Severance Pay    10.44.2 to PNM's Quarterly         1-6986
                Plan of Public Service Company of New Mexico dated     Report on Form 10-Q for the
                August 1, 1999.                                        quarter ended September 30,
                                                                       1999.

10.45**         Second Amendment to the Public Service Company of      10.45 to PNM's Quarterly           1-6986
                New Mexico Service Bonus Plan, as amended              Report on Form 10-Q for the
                effective  December 7, 1998                            quarter ended March 31, 1999.

10.47**         Compensation Arrangement with Chief Executive          10.3 to PNM's Quarterly            1-6986
                Officer, Benjamin F. Montoya effective June 23, 1993.  Report on Form 10-Q for the
                                                                       quarter ended June 30, 1993.

E-13

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                  File No:
----------          ----------------------                            -----------------                  --------
10.47.1**       Pension Service Adjustment Agreement for Benjamin F.  10.3.1 to PNM's Quarterly         1-6986
                Montoya.                                              Report on Form 10-Q for the
                                                                      quarter ended September 30,
                                                                      1993.

10.47.2**       Severance Agreement for Benjamin F. Montoya.          10.3.2 to PNM's Quarterly         1-6986
                                                                      Report on Form 10-Q
                                                                      for the quarter ended
                                                                      September 30, 1993.

10.47.4**       First Amendment to the Pension Service Adjustment     10.47.4 to PNM's Quarterly         1-6986
                Agreement for Benjamin F. Montoya.                    Report on Form 10-Q for the
                                                                      quarter ended June 30, 1998.

10.47.6**       Second Amendment to the Pension Service Adjustment    10.47.6 to PNM's Quarterly         1-6986
                Agreement for Benjamin F. Montoya, as amended         Report on Form 10-Q for the
                effective December 7, 1998                            quarter ended March 31, 1999.

10.48**         Public Service Company of New Mexico OBRA `93         10.4 to PNM's Quarterly            1-6986
                Retirement Plan.                                      Report on Form 10-Q for the
                                                                      quarter ended September 30,
                                                                      1993.

10.48.1**       First Amendment to the Public Service Company of      10.48.1 to PNM's Quarterly         1-6986
                New Mexico OBRA '93 Retirement Plan, as  amended      Report on Form 10-Q for the
                effective December 7, 1998                            quarter ended March 31, 1999.

10.49**         Employment Contract By and Between Public Service     10.49 to PNM's Annual Report       1-6986
                Company of New Mexico and Roger J. Flynn.             on Form 10-K for fiscal year
                                                                      ended December 31, 1994.

10.50**         Public Service Company of New Mexico Section 415      10.50 to PNM's Annual Report       1-6986
                Plan dated January 1, 1994.                           on Form 10-K for fiscal year
                                                                      ended December 31, 1993.

10.51.2**       First Restated and Amended Executive Retention Plan,  10.51.2 to PNM's Quarterly         1-6986
                as amended effective December 7, 1998                 Report on Form 10-Q for the
                                                                      quarter ended March 31, 1999.

E-14



Exhibit No.         Description of Exhibit                            Filed as Exhibit:                  File No:
----------          ----------------------                            -----------------                  --------
10.53        January 12, 1994 Stipulation.                            10.53 to PNM's Annual Report       1-6986
                                                                      on Form 10-K for fiscal year
                                                                      ended December 31, 1993.

10.54.1**    Health Care and Retirement Benefit Agreement             10.54.1 to PNM's Quarterly         1-6986
             By and Between the Public Service Company of             Report on Form 10-Q for the
             New Mexico and John T. Ackerman dated February           quarter ended March 31, 1994.
             1, 1994.

10.56.1      Amended and Restated Receivables Purchase Agreement      10.56.1 to PNM's Quarterly         1-6986
             dated May 20, 1996, between Public Service Company of    Report on Form 10-Q for the
             New Mexico, Citibank and Citicorp North America, Inc.    quarter ended June 30, 1996.
             and Amended Restated Collection Agent Agreement dated
             May 20, 1996, between Public Service Company of New
             Mexico, Corporate Receivables Corporation and Citibank,
             N.A.

10.59*       Amended and Restated Lease dated as of September 1,      10.59 to PNM's Annual              1-6986
             1993, between The First National Bank of Boston,         Report on Form 10-K for
             Lessor, and PNM, Lessee (EIP Lease).                     fiscal year ended December
                                                                      31, 1993.

10.61        Participation Agreement dated as of June 30, 1983        10.61 to PNM's Annual              1-6986
             among  Security Trust Company, as Trustee, PNM, Tucson   Report on Form 10-K for
             Electric Power Company and certain financial             fiscal year ended December
             institutions relating to the San Juan Coal Trust         31, 1993.
             (refiled).

10.62        Agreement of PNM pursuant to Item 601(b)(4)(iii) of      10.62 to PNM's Annual              1-6986
             Regulation S-K (refiled).                                Report on Form 10-K for
                                                                      fiscal year ended December
                                                                      31, 1993.

10.64**      Results Pay                                              10.64 to PNM's Quarterly           1-6986
                                                                      Report on Form 10-Q for the
                                                                      quarter ended March 31,
                                                                      1995.

10.65        Agreement for Contract Operation and Maintenance of the  10.64 to PNM's Quarterly           1-6986
             City of Santa Fe Water Supply Utility System, dated      Report on Form 10-Q for the
             July 3, 1995.                                            quarter ended June 30, 1995.

10.67        New Mexico Public Service Commission Order dated July    10.67 to PNM's Annual              1-6986
             30, 1987, and Exhibit I thereto, in NMPUC Case No.       Report on Form 10-K for
             2004, regarding the PVNGS decommissioning trust fund     fiscal year ended December
             (refiled).                                               31, 1997.

                                      E-15

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                 File No:
----------          ----------------------                            -----------------                 --------
10.68        Master Decommissioning Trust Agreement for Palo Verde    10.68 to PNM's Quarterly          1-6986
             Nuclear Generating Station dated March 15, 1996, Report  on Form 10-Q for the
             between Public Service Company of New Mexico and         quarter ended March 31,
             Mellon  Bank, N.A.                                       1996.

10.68.1      Amendment Number One to the Master Decommissioning       10.68.1 to PNM's Annual           1-6986
             Trust Agreement for Palo Verde Nuclear Generating        Report of the Registrant on
             Station dated January 27, 1997, between Public Service   Form 10-K for fiscal year
             Company of New Mexico and Mellon Bank, N.A.              ended December 31, 1997.

10.69*       Refunding Agreement No. 3 dated as of September 27,      10.69 to PNM's Quarterly          1-6986
             1996 between Public Service Company of New Mexico,       Report on Form 10-Q
             The Owner Participant named therein, State               for the quarter ended
             Street Bank and Trust Company, as Owner Trustee,         September 30, 1996.
             The Chase Manhattan, Bank, as Indenture
             Trustee, and First PV Funding Corporation.

10.72        Revolving Credit Agreement dated as of March 11,         10.72 to PNM's Quarterly          1-6986
             1998, among PNM,                                         Report on Form 10-Q for the
             the Chase Manhattan Bank, Citibank,                      quarter ended March 31,
             N.A., Morgan Guaranty Trust Company                      1998.
             of New York, and Chase Securities, Inc.,
             and the Initial Lenders Named Therein.

10.73        Refunding Agreement No. 8A, dated as                     10.73 to PNM's Quarterly          1-6986
             of December 23, 1997, among PNM, the Owner               Report on Form 10-Q for the
             Participant Named                                        quarter ended March 31,
             Therein, State Street Bank and Trust                     1998.
             Company, as Owner Trustee, The Chase
             Manhattan Bank, as Indenture Trustee,
             and First PV Funding Corporation.

10.74**      Third Restated and Amended Public                        10.74 to PNM's Quarterly          1-6986
             Service Company of New Mexico                            Report on Form 10-Q for the
             Performance Stock Plan effective March 10, 1998.         quarter ended March 31,
                                                                      1998.

10.74.1**    First Amendment to the Third Restated                    10.74.1 to PNM's Quarterly        1-6986
             and Amended Public Service Company                       Report on Form 10-Q for the
             of New Mexico Performance Stock Plan                     quarter ended March 31,
             Dated February 7, 2000                                   2000.

E-16

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                  File No:
----------          ----------------------                            -----------------                  --------

10.74.2**      Second Amendment to the Third Restated and Amended     10.74.2 to PNM's Annual
               Public Service Company of New Mexico Performance       Report on Form 10-K for the
               Stock Plan, effective December 7, 1998                 fiscal year ended December
                                                                      31, 2000.

10.74.3**      Third Amendment to the Third Restated and Amended      10.74.3 to PNM's Annual
               Public Service Company of New Mexico Performance       Report on Form 10-K for the
               Stock Plan, effective December 10, 2000.               fiscal year ended December
                                                                      31, 2000.

10.74.4**      Fourth Amendment to Third Restated and Amended Public  4.3.5 to PNM Resources'          333-03303
               Service Company of New Mexico Performance Stock Plan   Post-Effective Amendment
               dated December 31, 2001                                No. 1 to Form 8
                                                                      Registration Statement
                                                                      filed December 31, 2001

10.75**        First Amended and Restated Public Service Company of   10.75 to PNM Resources and         1-6986
               New Mexico Executive Savings Plan dated November 16,   PNM's Annual Report on Form
               2001.                                                  10-K for the fiscal year
                                                                      ended December 31, 2001

10.75.1**      First Amendment to the First Amended and Restated      4.6 to PNM Resources' Form       333-76316
               Public Service Company of New Mexico Executive         8 Registration Statement
               Savings Plan effective January 1, 2002                 filed January 4, 2002

10.76          PVNGS Capital Trust--Variable Rate                     10.76 to PNM's Quarterly           1-6986
               Trust Notes--PVNGS Note Agreement                      Report on Form 10-Q for the
               dated as of July 31, 1998.                             quarter ended September 30,
                                                                      1998.

10.77          San Juan Project Participation Agreement dated as of   10.77 to PNM's Quarterly           1-6986
               October 27, 1999, among Public Service Company of New  Report on Form 10-Q for the
               Mexico, Tucson Electric Power Company, The City of     quarter ended September 30,
               Farmington, New Mexico, M-S-R Public Power Agency,     1999.
               The Incorporated County of Los Alamos, New Mexico,
               Southern California Public Power Authority, City of
               Anaheim, Utah Associated Municipal Power System and
               Tri-State Generation and Transmission Association, Inc.

E-17



Exhibit No.         Description of Exhibit                            Filed as Exhibit:                 File No:
----------          ----------------------                            -----------------                 --------
10.78          Stipulation in the matter of the Commission's          10.78 to PNM's Quarterly          1-6986
               investigation of the rates for electric service of     Report on Form 10-Q for the
               Public Service Company of New Mexico, Rate Case No.    quarter ended September 30,
               2761, dated May 21, 1999                               1999.

10.78.1        Stipulation in the matter of the Commission's          10.78.1 to PNM's Quarterly        1-6986
               investigation of the rates for electric service of     Report on Form 10-Q for the
               Public Service Company of New Mexico, Rate Case No.    quarter ended September 30,
               2761, dated May 27, 1999                               1999.

10.79          Asset Sale Agreement between Tri-State Generation and  10.79 to PNM's Quarterly          1-6986
               Transmission Association, Inc., a Colorado             Report on Form 10-Q for the
               Cooperative Association and Public Service Company of  quarter ended September 30,
               New Mexico, a New Mexico Corporation, dated September  1999.
               9, 1999

10.80**        Supplemental Employee Retirement                       10.80 to PNM's Quarterly          1-6986
               Agreement, dated March 14, 2000 for                    Report on Form 10-Q for the
               Patrick T. Ortiz                                       quarter ended March 31, 2000

10.81**        Supplemental Employee Retirement                       10.81 to PNM's Quarterly          1-6986
               Agreement, dated March 22, 2000 for                    Report on Form 10-Q for the
               Jeffry E. Sterba                                       quarter ended March 31,
                                                                      2000.

10.82          PNM Resources, Inc. Omnibus Performance Equity Plan    4.3 to PNM Resources' Form      333-76288
               dated December 31, 2001                                8 Registration Statement
                                                                      filed January 4, 2001

E-18

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                  File No:
----------          ----------------------                            -----------------                  --------
10.83          Transportation Agreement Buy Out Agreement, dated      10.83 to PNM's Quarterly
               August 31, 2001 among San Juan Transportation          Report on Form 10-Q for the
               Company, PNM and Tucson Electric Power Company.        quarter ending September
                                                                      31, 2001 (Confidential
                                                                      treatment was requested
                                                                      to portions of this
                                                                      exhibit, and such
                                                                      portions were omitted
                                                                      from this exhibits
                                                                      filed and were filed
                                                                      separately with the
                                                                      Securities and Exchange
                                                                      Commission.)

10.84          Coal Sales Agreement Buy Out Agreement, dated August   10.8 4 to PNM's Quarterly
               31, 2001 among San Juan Coal Company, PNM and Tucson   Report on Form 10-Q for the
               Electric Power Company.                                quarter ending September
                                                                      31, 2001  (Confidential
                                                                      treatment was requested to
                                                                      portions of this exhibit,
                                                                      and such portions were
                                                                      omitted from this exhibits
                                                                      filed and were filed
                                                                      separately with the
                                                                      Securities and Exchange
                                                                      Commission.)

10.85          Underground Coal Sales Agreement, dated August 31,     10.85 to PNM's Quarterly
               2001 among San Juan Coal Company, PNM and Tucson       Report on Form 10-Q for the
               Electric Power Company.                                quarter ending September
                                                                      31, 2001  (Confidential
                                                                      treatment was requested to
                                                                      portions of this exhibit,
                                                                      and such portions were
                                                                      omitted from this exhibits
                                                                      filed and were filed
                                                                      separately with the
                                                                      Securities and Exchange
                                                                      Commission).

E-19

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                  File No:
----------          ----------------------                            -----------------                  --------

Additional Exhibits
99.2*         Participation Agreement dated as of                     99.2 to PNM's Annual Report       1-6986
              December 16, 1985, among the Owner                      on Form 10-K for fiscal
              Participant named therein, First PV                     year ended December 31,
              Funding Corporation. The First National                 1995.
              Bank of Boston, in its individual capacity
              and as Owner Trustee (under a Trust
              Agreement dated as of December 16, 1985
              with the Owner Participant), Chemical
              Bank, in its individual capacity and as
              Indenture Trustee (under a Trust
              Indenture, Mortgage, Security Agreement
              and Assignment of Rents dated as of
              December 16, 1985 with the Owner
              Trustee), and Public Service Company of
              New Mexico, including Appendix A
              definitions together with Amendment No. 1 dated July
              15, 1986 and Amendment No. 2 dated November 18, 1986
              (refiled).

99.3          Trust Indenture, Mortgage, Security                     99.3 to PNM's Quarterly           1-6986
              Agreement and Assignment of Rents                       Report on Form 10-Q for the
              dated as of December 16, 1985, between                  quarter ended March 31,
              the First National Bank of Boston, as                   1996.
              Owner Trustee, and Chemical Bank, as
              Indenture Trustee together with
              Supplemental Indentures Nos. 1 and 2
              (refiled).

99.3.3        Supplemental Indenture No. 3 dated as                   99.3.3 to PNM's Quarterly         1-6986
              of March 8, 1995, to Trust Indenture                    Report on Form 10-Q for the
              Mortgage, Security Agreement and                        quarter ended March 31,
              Assignment of Rents between The First                   1995.
              National Bank of Boston and Chemical
              Bank dated as of December 16, 1985.

99.4*         Assignment, Assumption and Further                      99.4 to PNM's Annual Report       1-6986
              Agreement dated as of December 16,                      on Form 10-K for fiscal
              1985, between Public Service Company                    year ended December 31,
              of New Mexico and The First National                    1995.
              Bank of Boston, as Owner
              Trustee (refiled).

99.5          Participation Agreement dated as of July                99.5 to PNM's Annual Report       1-6986
              31, 1986, among the Owner Participant                   on Form 10-K for fiscal
              named herein, First PV Funding                          year ended December 31,
              Corporation, The First National Bank of                 1996.
              Boston, in its individual capacity and as Owner
              Trustee (under a Trust Agreement dated as of July
              31, 1986, with the Owner Participant), Chemical Bank,
              in its individual capacity and as Indenture Trustee
              (under a Trust Indenture, Mortgage, Security Agreement
              and Assignment of Rents dated as of July 31, 1986,
              with the Owner Trustee), and Public Service Company
              of New Mexico, including Appendix A definitions
              together with Amendment No. 1 thereto (refiled).

E-20

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                 File No:
----------          ----------------------                            -----------------                 --------
99.6          Trust Indenture, Mortgage, Security                     99.6 to PNM's Annual Report       1-6986
              Agreement and Assignment of Rents                       on Form 10-K for fiscal
              dated as of July 31, 1986, between The                  year ended December 31,
              First National Bank of Boston, as Owner                 1996.
              Trustee, and Chemical Bank, as Indenture
              Trustee together with Supplemental Indenture
              No. 1 thereto (refiled).

99.7          Assignment, Assumption, and Further                     99.7 to PNM's Annual Report       1-6986
              Agreement dated as of July 31, 1986,                    on Form 10-K for fiscal
              between Public Service Company of                       year ended December 31,
              New Mexico and The First National Bank                  1996.
              of Boston, as Owner Trustee (refiled).

99.8          Participation Agreement dated as of                     99.8 to PNM's Quarterly           1-6986
              August 12, 1986, among the Owner                        Report on Form 10-Q for the
              Participant named therein, First PV                     quarter ended March 31,
              Funding Corporation. The First National                 1997.
              Bank of Boston, in its individual capacity
              and as Owner Trustee (under a Trust
              Agreement dated as of August 12, 1986,
              with the Owner Participant), Chemical Bank,
              in its individual capacity and as Indenture
              Trustee (under a Trust Indenture, Mortgage,
              Security Agreement and Assignment of Rents
              dated as of August 12, 1986, with the Owner
              Trustee), and Public Service Company of New
              Mexico, including Appendix A definitions
              (refiled).

99.8.1*       Amendment No. 1 dated as of November                    99.8.1 to PNM's Quarterly         1-6986
              18, 1986, to Participation Agreement                    Report on Form 10-Q for the
              dated as of August 12, 1986 (refiled).                  quarter ended March 31,
                                                                      1997.

99.9*         Trust Indenture, Mortgage, Security                     99.9 to PNM's Annual Report       1-6986
              Agreement and Assignment of Rents                       of the Registrant on Form
              dated as of August 12, 1986, between the                10-K for fiscal year ended
              First National Bank of Boston, as Owner                 December 31, 1996.
              Trustee, and Chemical Bank, as Indenture
              Trustee together with Supplemental
              Indenture No. 1 thereto (refiled).

E-21

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                 File No:
----------          ----------------------                            -----------------                 --------
99.9.2        Supplemental Indenture No. 2 dated as                   99.9.1 to PNM's Quarterly         1-6986
              of March 8, 1995, to Trust Indenture,                   Report on Form 10-Q for the
              Mortgage, Security Agreement and                        quarter ended March 31,
              Assignment of Rents between The First                   1995.
              National Bank of Boston and Chemical
              Bank dated as of August 12, 1986.

99.10*        Assignment, Assumption, and Further                     99.10 to PNM's Quarterly          1-6986
              Agreement dated as of August 12, 1986,                  Report on Form 10-Q for the
              between Public Service Company of New                   quarter ended March 31,
              Mexico and The First National Bank of                   1997.
              Boston, as Owner
              Trustee (refiled).

99.11*        Participation Agreement dated as of December 15, 1986,  99.1 to PNM's Quarterly           1-6986
              among the Owner Participant named therein, First PV     Report on Form 10-Q for the
              Funding Corporation, The First National Bank of         quarter ended March 31, 1997.
              Boston, in its individual capacity and as Owner
              Trustee (under a Trust Agreement dated as of December
              15, 1986, with the Owner Participant), Chemical Bank,
              in its individual capacity and as Indenture Trustee
              (under a Trust Indenture, Mortgage, Security Agreement
              and Assignment of Rents dated as of December 15, 1986,
              with the Owner Trustee), and Public Service Company of
              New Mexico, including Appendix A definitions (Unit 1
              Transaction) (refiled).

99.12         Trust Indenture, Mortgage, Security                     99.12 to PNM's Quarterly          1-6986
              Agreement and Assignment of Rents                       Report on Form 10-Q for the
              dated as of December 15, 1986, between                  quarter ended March 31,
              The First National Bank of Boston, as                   1997.
              Owner Trustee, and Chemical Bank, as
              Indenture Trustee (Unit 1 Transaction)
              (refiled).

99.13         Assignment, Assumption and Further                      99.13 to PNM's                    1-6986
              Agreement dated as of December 15,                      Quarterly Report on Form
              1986, between Public Service Company                    10-Q for the quarter ended
              of New Mexico and The First National                    March 31, 1997.
              Bank of Boston, as Owner Trustee
              (Unit 1 Transaction) (refiled).

E-22

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                 File No:
----------          ----------------------                            -----------------                 --------
99.14         Participation Agreement dated as of December 15, 1986,  99.14 to PNM's                    1-6986
              among the Owner Participant named therein, First PV     Quarterly Report on Form
              Funding Corporation, The First National Bank of         10-Q for the quarter ended
              Boston, in its individual capacity and as Owner         March 31, 1997.
              Trustee (under a Trust Agreement dated as of December
              15, 1986, with the Owner Participant), Chemical Bank,
              in its individual capacity and as Indenture Trustee
              (under a Trust Indenture, Mortgage, Security Agreement
              and Assignment of Rents dated as of December 15, 1986,
              with the Owner Trustee), and Public Service Company of
              New Mexico, including Appendix A definitions (Unit 2
              Transaction) (refiled).

99.15         Trust Indenture, Mortgage, Security                     99.15 to PNM's Annual             1-6986
              Agreement and Assignment of Rents dated                 Report on Form 10-K for
              as of December 31, 1986, between the                    fiscal year ended December
              First National Bank of Boston, as Owner                 31, 1996.
              Trustee, and Chemical Bank, as Indenture
              Trustee (Unit 2 Transaction) (refiled).

99.16         Assignment, Assumption, and Further                     99.16 to PNM's Quarterly          1-6986
              Agreement dated as of December 15,                      Report on Form 10-Q for the
              1986, between Public Service Company                    quarter ended March 31,
              New Mexico and The First National                       1997.
              Bank of Boston, as Owner Trustee
              (Unit 2 Transaction) (refiled).

99.17*        Waiver letter with respect to "Deemed                   99.17 to PNM's Annual             1-6986
              Loss Event" dated as of August 18, 1986,                Report on Form 10-K for
              between the Owner Participant named                     fiscal year ended December
              therein, and Public Service Company of                  31, 1996.
              New Mexico (refiled).

99.18*        Waiver letter with respect to Deemed                    99.18 to PNM's Annual             1-6986
              Loss Event" dated as of August 18, 1986,                Report on Form 10-K for
              between the Owner Participant named                     fiscal year ended December
              therein, and Public Service Company of                  31, 1996.
              New Mexico (refiled).

99.19         Agreement No. 13904 (Option and Purchase of Effluent),  99.19 to PNM's Annual             1-6986
              dated April 23, 1973, among Arizona Public Service      Report on Form 10-K for
              Company, Salt River Project Agricultural Improvement    fiscal year ended December
              and Power District, the Cities of Phoenix, Glendale,    31, 1996.
              Mesa, Scottsdale, and Tempe, and the Town of Youngtown
              (refiled).

E-23

Exhibit No.         Description of Exhibit                            Filed as Exhibit:                 File No:
----------          ----------------------                            -----------------                 --------
99.20         Agreement for the Sale and Purchase of                  99.20 to PNM's Annual             1-6986
              Wastewater Effluent, dated June 12, 1981,               Report on Form 10-K for
              Among Arizona Public Service Company,                   fiscal year ended December
              Salt River Project Agricultural                         31, 1996.
              Improvement and Power District and the
              City of Tolleson, as amended (refiled).

99.21*        1996 Supplemental Indenture dated as of                 99.21 to PNM's Quarterly          1-6986
              September 27, 1996 to Trust Indenture,                  Report on Form 10-Q for the
              Mortgage, Security Agreement and                        quarter ended September 30,
              Assignment of Rents dated as of December                1996.
              16, 1985 between State Street Bank and
              Trust Company, as Owner Trustee, and
              The Chase Manhattan Bank, as Indenture
              Trustee.

99.22         1997 Supplemental Indenture, dated as of                99.22 to PNM's Quarterly          1-6986
              December 23, 1997, to Trust Indenture,                  Report on Form 10-Q for the
              Mortgage, Security Agreement and                        quarter ended March 30,
              Assignment of Rents, dated as of August                 1998.
              12, 1986, between State Street Bank and
              Trust, as Owner Trustee, and The Chase
              Manhattan Bank, as Indenture Trustee.


* One or more additional documents, substantially identical in all material respects to this exhibit, have been entered into, relating to one or more additional sale and leaseback transactions. Although such additional documents may differ in other respects (such as dollar amounts and percentages), there are no material details in which such additional documents differ from this exhibit.

** Designates each management contract or compensatory plan or arrangement required to be identified pursuant to paragraph 3 of Item 14(a) of Form 10-K.

E-24

(b) Reports on Form 8-K:

During the quarter ended December 31, 2002 and during the period beginning January 1, 2003 and ending March 12, 2003, the Company filed, on the date indicated, the following reports on Form 8-K.

     Dated:                          Filed:                                Relating to:
     ------                          ------                                ------------
October 1, 2002                  October 4, 2002                The Company declares common stock
                                                                dividend.

October 10, 2002                 October 11, 2002               The Company announces to set five-year rate
                                                                path and projected cost savings will offset
                                                                lower rates.

September 30, 2002               October 15, 2002               The Company's Comparative Operating
                                                                Statistics for the months of September 2002
                                                                and 2001 and the years ended September 2002
                                                                and 2001.

October 21, 2002                 October 22, 2002               The Company entered into an agreement with
                                                                FPL Energy LLC, a subsidiary of FPL Group,
                                                                Inc., to develop a 200 MW wind generation
                                                                facility in New Mexico.

October 29, 2002                 October 30, 2002               The Company's quarter ended September 30,
                                                                2002 Earnings Announcement, Consolidated
                                                                Statement of Earnings, Consolidated Balance
                                                                Sheets, Consolidated Statement of Cash Flow
                                                                and Comparative Operating Statistics.

October 31, 2002                 November 14, 2002              The Company's Comparative Operating
                                                                Statistics for the months of October 2002 and
                                                                2001 and the years ended October 2002
                                                                and 2001.

December 9, 2002                 December 10, 2002              The Company declares preferred dividends.

December 10, 2002                December 11, 2002              The Company declares common stock
                                                                dividend.

December 10, 2002                December 11, 2002              The Company names new CFO, out-going
                                                                CFO to lead corporate strategy and
                                                                technology efforts.

November 30, 2002                December 19, 2002              The Company's Comparative Operating
                                                                Statistics for the months of November 2002
                                                                and 2001 and the years ended November 2002
                                                                and 2001.

E-25

     Dated:                          Filed:                               Relating to:
     ------                          ------                               ------------
January 2, 2003                  January 3, 2003                The Company updates 2002 earnings
                                                                guidance, provides guidance for 2003.

January 3, 2003                  January 3, 2003                The Company's utility unit expands
                                                                revolving  credit agreement.  The Company
                                                                also purchases lease of major NM-Texas
                                                                Transmission lines.

January 10, 2003                 January 10, 2003               The Company's utility unit seeks increase in
                                                                natural gas cost of service.

January 14, 2003                 January 14, 2003               The Company's Comparative Operating
                                                                Statistics for the months of
                                                                December 2002 and 2001 and the
                                                                years ended December 2002 and 2001.

January 28, 2003                 January 29, 2003               The Company announces the New Mexico
                                                                Public Regulation Commission approves
                                                                the Company's Electric Rate Agreement.

January 29, 2003                 January 31, 2003               The Company wins 80 MW San Diego
                                                                Navy Contract.

February 11, 2003                February 12, 2003              The Company's quarter ended December 31,
                                                                2002 Earnings Announcement, Unaudited
                                                                Consolidated Statement of Earnings,
                                                                Unaudited Consolidated Balance Sheets,
                                                                Unaudited Consolidated Statement of Cash
                                                                Flows, Comparative Operating Statistics
                                                                and Other Select Financial Information

E-26

SIGNATURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

PNM RESOURCES, INC.
(Registrant)

Date:  March 18, 2003                     By           /s/ J. E. STERBA
                                            -----------------------------------
                                                          J. E. Sterba
                                                    Chairman, President and
                                                    Chief Executive Officer

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the Registrant and in the capacities and on the dates indicated.

           Signature                               Capacity                               Date
           ---------                               --------                               ----
       /s/ J. E. STERBA                  Principal Executive Officer and             March 18, 2003
------------------------------                Chairman of the Board
          J. E. Sterba
   Chairman, President and
    Chief Executive Officer

       /s/ J. R. LOYACK                  Principal Financial Officer                 March 18, 2003
------------------------------
         J. R. Loyack
   Senior Vice President and
    Chief Financial Officer

       /s/ R. A. LUMNEY                  Principal Accounting Officer                March 18, 2003
------------------------------
         R. A. Lumney
Vice President, Controller and
   Chief Accounting Officer

      /s/ R. G. ARMSTRONG                Director                                    March 18, 2003
------------------------------
        R. G. Armstrong

       /s/ R. M. CHAVEZ                  Director                                    March 18, 2003
------------------------------
         R. M. Chavez

       /s/ J. A. DOBSON                  Director                                    March 18, 2003
------------------------------
         J. A. Dobson

       /s/ J. A. GODWIN                  Director                                    March 18, 2003
------------------------------
         J. A. Godwin

       /s/ M. T. PACHECO                 Director                                    March 18, 2003
------------------------------
         M. T. Pacheco

      /s/ T. F. PATLOVICH                Director                                    March 18, 2003
------------------------------
        T. F. Patlovich

        /s/ R. M. PRICE                  Director                                    March 18, 2003
------------------------------
          R. M. Price

        /s/ B. S. REITZ                  Director                                    March 18, 2003
------------------------------
          B. S. Reitz

        /s/ P. F. ROTH                   Director                                    March 18, 2003
------------------------------
          P. F. Roth

E-27

CERTIFICATIONS:

I, Jeffry E. Sterba, certify that:

1. I have reviewed this annual report on Form 10-K of PNM Resources, Inc. and Public Service Company of New Mexico;

2. Based on my knowledge, this annual report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this annual report;

3. Based on my knowledge, the financial statements, and other financial information included in this annual report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this annual report;

4. The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

a) designed such disclosure controls and procedures to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this annual report is being prepared;

b) evaluated the effectiveness of the registrant's disclosure controls and procedures as of a date within 90 days prior to the filing date of this annual report (the "Evaluation Date"); and

c) presented in this annual report our conclusions about the effectiveness of the disclosure controls and procedures based on our evaluation as of the Evaluation Date;

5. The registrant's other certifying officers and I have disclosed, based on our most recent evaluation, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent function):

a) all significant deficiencies in the design or operation of internal controls which could adversely affect the registrant's ability to record, process, summarize and report financial data and have identified for the registrant's auditors any material weaknesses in internal controls; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal controls; and

E-28

6. The registrant's other certifying officers and I have indicated in this annual report whether or not there were significant changes in internal controls or in other factors that could significantly affect internal controls subsequent to the date of our most recent evaluation, including any corrective actions with regard to significant deficiencies and material weaknesses.

March 18, 2003

/s/ Jeffry E. Sterba
----------------------------------
Jeffry E. Sterba,
Chairman, President and
Chief Executive Officer

E-29

I, Max H. Maerki, certify that:

1. I have reviewed this annual report on Form 10-K of PNM Resources, Inc. and Public Service Company of New Mexico;

2. Based on my knowledge, this annual report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this annual report;

3. Based on my knowledge, the financial statements, and other financial information included in this annual report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this annual report;

4. The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

a) designed such disclosure controls and procedures to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this annual report is being prepared;

b) evaluated the effectiveness of the registrant's disclosure controls and procedures as of a date within 90 days prior to the filing date of this annual report (the "Evaluation Date"); and

c) presented in this annual report our conclusions about the effectiveness of the disclosure controls and procedures based on our evaluation as of the Evaluation Date;

5. The registrant's other certifying officers and I have disclosed, based on our most recent evaluation, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent function):

a) all significant deficiencies in the design or operation of internal controls which could adversely affect the registrant's ability to record, process, summarize and report financial data and have identified for the registrant's auditors any material weaknesses in internal controls; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal controls; and

E-30

6. The registrant's other certifying officers and I have indicated in this annual report whether or not there were significant changes in internal controls or in other factors that could significantly affect internal controls subsequent to the date of our most recent evaluation, including any corrective actions with regard to significant deficiencies and material weaknesses.

March 18, 2003

/s/ Max H. Maerki
----------------------------------
Max H. Maerki,
Senior Vice President,
Corporate Strategy and Development
Former Senior Vice President and
Chief Financial Officer during the fiscal
year ended on December 31, 2002

E-31

I, John R. Loyack, certify that:

1. I have reviewed this annual report on Form 10-K of PNM Resources, Inc. and Public Service Company of New Mexico;

2. Based on my knowledge, this annual report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this annual report;

3. Based on my knowledge, the financial statements, and other financial information included in this annual report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this annual report;

4. The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant and we have:

a) designed such disclosure controls and procedures to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this annual report is being prepared;

b) evaluated the effectiveness of the registrant's disclosure controls and procedures as of a date within 90 days prior to the filing date of this annual report (the "Evaluation Date"); and

c) presented in this annual report our conclusions about the effectiveness of the disclosure controls and procedures based on our evaluation as of the Evaluation Date;

5. The registrant's other certifying officers and I have disclosed, based on our most recent evaluation, to the registrant's auditors and the audit committee of registrant's board of directors (or persons performing the equivalent function):

a) all significant deficiencies in the design or operation of internal controls which could adversely affect the registrant's ability to record, process, summarize and report financial data and have identified for the registrant's auditors any material weaknesses in internal controls; and

b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal controls; and

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6. The registrant's other certifying officers and I have indicated in this annual report whether or not there were significant changes in internal controls or in other factors that could significantly affect internal controls subsequent to the date of our most recent evaluation, including any corrective actions with regard to significant deficiencies and material weaknesses.

March 18, 2003

/s/ John R. Loyack
----------------------------------
John R. Loyack,
Senior Vice President and
Chief Financial Officer

E-33

EXHIIBIT 3.2

BYLAWS
OF
PNM RESOURCES, INC.

With all Amendments to and Including February 18, 2003

BYLAWS

OF

PNM RESOURCES, INC.

ARTICLE I
MEETINGS OF SHAREHOLDERS

Section 1. Meetings

The annual meeting of shareholders shall be held at the time and place set by resolution of the Board of Directors for the election of directors and the transaction of such other business as may properly come before the meeting.

Special meetings may be called by a majority of the Board of Directors, the Chairman of the Board, the President or by holders of not less than one-tenth of all the shares entitled to vote at the meeting.

Section 2. Notice

Written notice of any meeting stating the time and place, and if a special meeting, the purpose, of the meeting shall be mailed to each shareholder of record entitled to vote at the meeting at the address of the shareholder as it appears on the stock transfer books of the Corporation, except as otherwise provided by law. Notices of special meetings called by a majority of the Board of Directors, the Chairman of the Board or the President, and of annual meetings shall be mailed not less than ten (10) days nor more than fifty (50) days before the meeting. Notices of other special shareholder meetings shall be mailed not less than forty (40) days nor more than fifty (50) days before the date of the meeting.

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Section 3. Adjournment

Whenever a quorum is not present at any meeting of the shareholders, or whenever it may be deemed desirable, a majority in interest of the shareholders present in person or by proxy may adjourn the meeting from time to time to any future date, without notice other than by announcement at the meeting. At any continuation of the adjourned meeting at which a quorum is present, any business may be transacted which might have been transacted at the meeting originally scheduled.

Section 4. Order of Business

(a) The Chairman of the Board, or in the absence of the Chairman, the President, or in their absence, a director designated by the Board of Directors, shall call meetings of the shareholders to order and shall act as Chairman of the meeting. The shareholders may appoint any shareholder or the proxy of any shareholder to act as Chairman of any meeting of the shareholders in the absence of the Chairman of the Board, President and a director designated by the Board to serve as Chairman of the meeting. The Secretary, or in the absence of the Secretary, an Assistant Secretary, shall act as Secretary at all meetings of the shareholders, but in the absence of the Secretary and Assistant Secretary at any meetings of the shareholders, the Chairman of the meeting may appoint any person to act as Secretary of the meeting.
(b) The Chairman of the meeting shall have the right to determine the order of business at the meeting, to prescribe the rules and procedures for the conduct of the meeting, and to do all things necessary or desirable for the proper conduct of the meeting, including maintenance of order and safety and limitations on the time allotted to questions or comments on the affairs of the Corporation.

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(c) The only business that may be conducted at an annual meeting of shareholders is that business which has been brought before the meeting: (i) by or at the direction of the Chairman of the meeting; (ii) pursuant to the notice of the meeting; or (iii) by any shareholder who is a holder of record at the time of the giving of the notice of the meeting who is entitled to vote at the meeting and who complies with the procedures set forth in Section 4 (d).

(d) For business to be properly brought before an annual meeting by a shareholder, the shareholder must have given timely notice of the proposal in proper written form to the Secretary of the Corporation. To be timely, a shareholder's notice must be delivered to or mailed and received at the Secretary's office at least ninety (90) days before the date on which the proxy materials for the prior year's annual meeting of shareholders were first mailed. To be in proper written form, a shareholder's notice to the Secretary shall set forth in writing as to each matter the shareholder proposes to bring before the annual meeting: (i) a brief description of the business desired to be brought before the annual meeting and the reasons for conducting the business at the annual meeting; (ii) the name and address of the shareholder proposing the business and all persons or entities acting in concert with the shareholder;
(iii) the class and number of shares of the Corporation which are beneficially owned by the shareholder and all persons or entities acting in concert with the shareholder; and (iv) any material interest of the shareholder in the proposed business. These notice requirements will be satisfied by a shareholder if the shareholder has notified the Secretary of the Corporation of his or her intention to present a proposal at an annual meeting and the proposal has been included in a proxy statement that has been prepared by management of the Corporation to solicit proxies for the annual meeting. If, however, the

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shareholder does not appear or send a qualified representative to present the proposal at the annual meeting, the proposal shall not be presented for a vote at the meeting, even though proxies regarding that vote have been received by the Corporation.

Section 5. Inspectors
At each meeting of the shareholders at which a vote by ballot is taken, the polls shall be opened and closed, the proxies and ballots shall be collected, and the validity of proxies and the acceptance or rejection of votes shall be decided by two inspectors. No person who is a candidate for the office of director shall act as inspector of any election for directors. The inspectors shall be appointed by the Board of Directors before the meeting or, if no appointment has been made, then by the Chairman of the meeting. If for any reason any of the inspectors previously appointed fails to attend or refuses or is unable to serve, those inspectors not serving shall be replaced by inspectors appointed by the Chairman of the meeting.

Section 6. Voting

At meetings of shareholders, every shareholder having voting rights as provided for in the Articles of Incorporation shall be entitled to one (1) vote for each share of stock outstanding in the name of the shareholder on the books of the Corporation on the date on which shareholders entitled to vote are determined or as otherwise provided for in the Articles of Incorporation. Each shareholder may be represented and vote by a proxy or proxies appointed by an instrument in writing or other manner authorized by the Board of Directors to the extent permitted by law. If the instrument designates two (2) or more persons to act as proxies, a majority of the proxies present at the meeting may exercise all of the powers conferred by the instrument unless the instrument provides otherwise. No proxy shall be voted at any meeting or continuation of an adjourned meeting other than that for which the proxy is given.

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In all elections for directors, voting shall be by written ballot, or by electronic, telephonic or other process as the Board of Directors may authorize, to the extent permitted by law.
The Board of Directors may fix a date in advance not exceeding fifty
(50) days before the date of any meeting of shareholders as a record date for the determination of shareholders entitled to notice of and to vote at the meeting. Only shareholders of record on the date so fixed shall be entitled to notice of and to vote at the meeting.

ARTICLE II
DIRECTORS

Section 1. Number, Election and Terms
The business and property of the Corporation shall be managed under the direction of the Board of Directors. The Board of Directors shall, by resolution, fix the number of directors which shall be no less than five (5) and no more than twelve (12) in number who shall be elected in three classes, as equal in number as possible, known as classes "A," "B" and "C."

(Effective July 1, 2001).

Section 2. Compensation
Directors shall receive compensation for their services as directors as may be fixed by resolution of the Board of Directors, including reimbursement for expenses for Board related services.

Section 3. Meetings

The meetings of the Board of Directors shall be held at the times and places designated by the Board of Directors. The annual meeting of the Board of Directors for the election of officers and such other business as may properly come before the meeting shall be held immediately following the annual meeting

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of shareholders. Special meetings of the Board of Directors shall be held whenever called at the direction of the Chairman of the Board, the President, or any two (2) directors if there are less than nine (9) directors on the Board, or any three (3) directors if there are nine (9) or more directors on the Board.

Section 4. Notice

No notice shall be required of any annual or regular meeting of the Board of Directors unless the place has been changed from that last designated by the Board of Directors. Notice of any annual or regular meeting, when required, or of any special meeting, of the Board of Directors shall be given to each director in writing or by telephone at least twenty-four (24) hours before the time fixed for the meeting. Notice may be waived by any director. Unless otherwise indicated in the notice, any and all business may be transacted at a special meeting. At any meeting at which every director is present, even without notice, any business may be transacted.

Section 5. Adjournments

Any annual, regular or special meeting of the Board of Directors may be adjourned from time to time by the members present whether or not a quorum is present, and no notice shall be required of any continuation of an adjourned meeting beyond the announcement at the adjourned meeting.

Section 6. Indemnification

Each person serving as a director or an officer of the Corporation, or, at the request of the Corporation, as a director or an officer of any other company in which the Corporation has a financial interest and regardless of whether or not the person is then in office, and the heirs, executors, administrators and personal representatives of the person, shall be indemnified by the Corporation to the full extent of the authority of the Corporation to so indemnify as authorized by New Mexico law.

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Section 7. Committees

The Board of Directors may designate from among its members one (1) or more committees, to exercise the power and authority and perform the functions that the Board may determine, except as may be limited by law.

ARTICLE III
CONTRACTS AND NEGOTIABLE INSTRUMENTS

Section 1. Authority to Sign Contracts
Unless the Board of Directors shall otherwise specifically direct, all contracts, instruments, documents or agreements of the Corporation shall be executed in the name of the Corporation by the President, or any Vice President, or any other employee, if approved by the President by either administrative policy letter or specific written designation. It shall not be necessary that the corporate seal be affixed to any contract.

Section 2. Authority to Sign Negotiable Instruments

Except as otherwise authorized by the Board of Directors, all checks, drafts, bills of exchange, promissory notes, electronic funds transfer documents, and other negotiable instruments shall be signed by the Chairman of the Board, President, any Vice President, Secretary or Treasurer. Facsimile signatures shall be sufficient to meet the requirements of this section.

Section 3. Approval by Shareholders

The Board of Directors in its discretion may submit any contract, or act, for approval or ratification at any annual meeting of the shareholders, or

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at any special meeting of the shareholders called for the purpose of considering the act or contract. Except as provided for in the Articles of Incorporation, any contract or act that shall be approved or ratified by the vote of the holders of a majority of the capital stock of the Corporation which is represented in person or by proxy at the meeting shall be valid and binding upon the Corporation.
ARTICLE IV

OFFICERS

Section 1. Number, Election and Term

The officers of the Corporation shall be a Chairman of the Board, a President, one or more Vice Presidents, a Secretary, a Treasurer, and a Controller, who shall be elected annually by the Board of Directors at the annual meeting and who shall hold office until the next annual meeting or until a successor is elected and qualifies. The Board of Directors may designate the Chairman of the Board or the President as Chief Executive Officer. The Board of Directors may elect one person to serve as both Chairman of the Board and President. The Board of Directors may designate one or more Vice Presidents as "Executive" Vice Presidents and one or more Vice Presidents as "Senior" Vice Presidents. The title of any Vice President may include words indicative of the area of responsibility of the Vice President. The Board of Directors shall designate one of the Vice Presidents as the chief financial officer of the Corporation. The Board of Directors may from time to time appoint such additional officers as the interest of the Corporation may require and fix their terms and duties of office. A vacancy occurring in any office may be filled by the Board of Directors. All officers shall hold office at the discretion of the Board of Directors and shall be subject to removal at any time by the affirmative vote of a majority of the whole Board of Directors. Election of any person as an officer of the Corporation shall not of itself create contract rights.

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Section 2. Chairman of the Board of Directors

The Chairman of the Board shall be elected annually by the Board of Directors at the annual meeting and shall hold that office until a successor is elected and qualifies. In the event of the incapacity of the Chairman of the Board, the Board of Directors shall, by a majority vote of the Board of Directors, designate an Acting Chairman who shall, during the incapacity of the Chairman of the Board, assume and perform all functions and duties which the Chairman of the Board is authorized or required by law to do. The Chairman of the Board shall have the power to call special meetings of the shareholders and of the directors for any purpose. The Chairman of the Board shall preside at all meetings of the shareholders and of the Board of Directors unless the Chairman of the Board is absent or incapacitated. The Chairman of the Board, subject to the authority of the Board of Directors, shall generally do and perform all acts incident to the office of the Chairman of the Board and which are authorized or required by law.

Section 3. President
The President shall provide active management over all operations of the Corporation subject to control of the Board of Directors. The President shall have the power to appoint and discharge, subject to the general approval or review by the Board of Directors, employees and agents of the Corporation and to fix their compensation, to make and sign contracts and agreements in the name of and on behalf of the Corporation and direct the general management and control of the business and affairs of the Corporation. The President may delegate authority to officers of the Corporation as the President may determine. The President shall have the power to segregate the operations of the Corporation into areas of responsibility. The President shall see that the books, reports, statements and certificates required by law are properly kept, made, and filed, and shall generally do and perform all acts which are

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authorized or required by law. The President shall designate a Vice President who shall, during the absence or incapacity of the President, assume and perform all functions and duties which the President might lawfully do if present in person and not under any incapacity.

Section 4. Vice Presidents

Each Vice President designated as "Executive" or "Senior Vice President" shall be responsible for the areas and activities assigned by the President, shall be subject to the authority of the President and shall assist in the general control and management of the business and affairs of the Corporation.

All other Vice Presidents shall be responsible for the areas and activities assigned by the President and shall perform other duties as may be required, including those assigned to an Executive or Senior Vice President during the absence or incapacity of the Executive or Senior Vice President.

Section 5. Secretary

The Secretary shall keep a record in the proper books provided for that purpose of meetings and proceedings of shareholders, the Board of Directors and Committees of the Board of Directors, and shall record all votes of the directors and shareholders in a book to be kept for that purpose. The Secretary shall notify the directors and shareholders of meetings as required by law or by the Bylaws of the Corporation and shall perform other duties as may be required by law or the Bylaws of the Corporation, or which may be assigned from time to time by the Board of Directors, Chairman of the Board or President. The Secretary is authorized to appoint one or more assistants from time to time as the Secretary deems advisable, the assistant or assistants to serve at the pleasure of the Secretary, and to perform the duties that are delegated by the Secretary. An assistant shall not be an officer of the Corporation.

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Section 6. Treasurer

The Treasurer shall have the custody of all the funds and securities of the Corporation, and shall have the power on behalf of the Corporation to sign checks, notes, drafts and other evidences of indebtedness, to borrow money for the current needs of the business of the Corporation and to make short-term investments of surplus funds of the Corporation. The Treasurer shall render to the Board of Directors, the Chairman of the Board or the President, whenever requested, an account of all transactions performed as Treasurer and of the financial condition of the Corporation. The Treasurer shall perform other duties as may be assigned by the Board of Directors, the Chairman of the Board or the President. The Treasurer is authorized to appoint one or more assistants from time to time as the Treasurer deems advisable, the assistant or assistants to serve at the pleasure of the Treasurer, and to perform the duties that are delegated by the Treasurer. An assistant shall not be an officer of the Corporation.

Section 7. Controller

The Controller shall be the chief accounting officer of the Corporation and have full responsibility and control of the accounting practices of the Corporation The Controller shall, subject to the approval of the Board of Directors, the Chairman of the Board or the President, establish accounting policies. The Controller shall standardize and coordinate accounting practices, supervise all accounting records and the presentation of all financial statements and tax returns. The Controller shall have other powers and duties as, from time to time, may be conferred by the Board of Directors, the Chairman of the Board or the President. The Controller is authorized to appoint one or more assistants from time to time as the Controller deems advisable, the assistant or assistants to serve at the pleasure of the Controller, and to perform the duties that are delegated by the Controller. An assistant shall not be an officer of the Corporation.

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Section 8. Form of Appointment

In making any appointments of assistants, the Secretary, Treasurer and Controller shall use the following form:

I, ________________ (Name), the duly elected _______________ (Title) of PNM Resources, Inc. do hereby appoint____________ (Name) to serve as Assistant _______________(Title) for the period of _______________(Date) to _______________(Date), unless this appointment is terminated earlier in writing, to assume or perform all functions and duties which I might require and, in my absence or incapacity, which I might lawfully do if present and not under any incapacity.

Any appointments of assistants by the Secretary, Treasurer or Controller and any terminations of appointments shall be maintained in the records of the Secretary's office.

ARTICLE V
CAPITAL STOCK

Section 1. Certificates of Stock

The name of the person owning shares of the capital stock of the Corporation, together with the number of shares and the date of issue, shall be entered on the Corporation's books. All certificates surrendered to the Corporation shall be canceled, and no new certificates shall be issued until a certificate or certificates aggregating the same number of shares of the same class have been surrendered or canceled. The Board of Directors may make proper provision, from time to time, for the issuance of new certificates in place of lost, destroyed or stolen certificates.

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Section 2. Transfer Agents and Registrars

The Corporation shall, if and whenever the Board of Directors determines, maintain one or more transfer offices or agencies, each in charge of a transfer agent designated by the Board of Directors, where the shares of the capital stock of the Corporation will be directly transferable, and also one or more registry offices, each in charge of a registrar designated by the Board of Directors, where shares of stock will be registered, and no certificates for shares of the capital stock of the Corporation, in respect of which one or more transfer agents and registrars shall have been designated, shall be valid unless countersigned by one of such transfer agents and registered by one of such registrars. The Board of Directors may also make additional rules and regulations as it may deem expedient concerning the issue, transfer and registration of certificates for shares of the capital stock of the Corporation.

Section 3. Shares Held for Account

The Board of Directors may adopt by resolution a procedure whereby a shareholder of the Corporation may certify in writing to the Corporation that all or a portion of the shares registered in the name of the shareholder are held for the account of a specified person or persons as provided for by New Mexico law.

Section 4. Transfer of Shares

Transfers of shares shall be made only upon the books of the Corporation by the holder or by the holder's attorney in fact upon surrender of certificates for a like number of shares.

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Section 5. Lost, Destroyed or Stolen Certificates
A new certificate of stock may be issued in the place of any certificate previously issued by the Corporation, or any predecessor of the Corporation, alleged to have been lost, destroyed or stolen. The Board of Directors may, in its discretion, require the owner of the lost, destroyed or stolen certificate to give to the Corporation satisfactory evidence that the certificate was lost, destroyed or stolen. The Board of Directors may also require a bond sufficient to indemnify it and its transfer agent, against any claim that may be made on account of the alleged loss of the certificate or the issuance of any new certificate.

Section 6. Fixing of Record Dates

For the purpose of determining shareholders entitled to notice of any meeting of shareholders, or entitled to receive payment of any dividend, or in order to make a determination of shareholders for any other proper purpose, the Board of Directors may, by resolution, provide that the stock transfer books be closed for a stated period not to exceed fifty (50) days. If the stock transfer books are closed for the purpose of determining shareholders entitled to notice of a meeting of shareholders, the books shall be closed for at least ten (10) days immediately prior to the meeting.

In lieu of closing the stock transfer books, the Board of Directors may, by resolution, fix in advance a date as the record date for any determination of shareholders, the date to be not more than fifty (50) days and, in case of a meeting of shareholders, not less than ten (10) days prior to the date on which the action requiring the determination of shareholders is to be taken.

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Section 7. Uncertificated Shares
The Corporation and each transfer agent designated by the Board of Directors are authorized to issue, register and transfer shares of capital stock of the Corporation (including fractional shares) in uncertificated book-entry form, provided that, within a reasonable time after the issuance or transfer of uncertificated shares, the corporation shall send, or cause the transfer agent to send, to the registered owner thereof a written notice containing the information required by applicable law.

ARTICLE VI
MISCELLANEOUS PROVISIONS

Section 1. Books
The books of the Corporation, except as otherwise provided by law, may be kept outside of the State of New Mexico, at such place or places as may be designated by the Board of Directors. The Board of Directors shall determine whether and to what extent, and at what time and places, and under what conditions and regulations, the accounts and the books of the Corporation, or any of them, shall be open to the inspection of shareholders; and no shareholder shall have any right to inspect any book or account or document of the Corporation except as conferred by the statutes of New Mexico, or authorized by the Board of Directors.

Section 2. Corporate Seal
The common corporate seal is, and until otherwise ordered by the Board of Directors shall be, an impression circular in form upon paper or wax bearing the words "PNM Resources, Inc. Incorporated 2000." The seal shall be in the charge of the Secretary. If and when directed by the Board of Directors, a duplicate of the seal may be kept and used by the Treasurer or by an Assistant Secretary or Assistant Treasurer.

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Section 3. Fiscal Year

The fiscal year of the Corporation shall be as determined by the Board of Directors.

Section 4. Principal Office

The principal office shall be established and maintained at a place designated by the Board of Directors.

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EXHIBIT 10.23.5

FIFTH AMENDMENT
TO THE RESTATED AND AMENDED
PUBLIC SERVICE COMPANY OF NEW MEXICO
ACCELERATED MANAGEMENT PERFORMANCE PLAN

THIS FIFTH AMENDMENT made by the Public Service Company of New Mexico ("PNM") is effective as of November 27, 2002.

WHEREAS, PNM adopted the Public Service Company of New Mexico Accelerated Management Performance Plan (the "Plan") as of January 14, 1981 to provide supplemental retirement benefits for certain employees;

WHEREAS, the Plan was amended and restated twice, most recently on August 16, 1988;

WHEREAS, the restated Plan has been amended numerous times, most recently effective as of December 7, 1998;

WHEREAS, PNM reserved the right to amend the Plan pursuant to Section 9.01 of the Plan; and

WHEREAS, PNM now desires to amend the Plan to: (i) change the name of the Plan; (ii) change the sponsor of the Plan to PNM Resources, Inc. ("PNMR"); and (iii) designate PNM as a participating employer.

NOW, THEREFORE, PNM does hereby amend the Plan as follows:

1. The name of the Plan is hereby amended to read as follows:

PNM RESOURCES, INC.
ACCELERATED MANAGEMENT PERFORMANCE PLAN

2. Section 1.01 of the Plan is hereby amended by the addition of the following paragraph to be placed at the end thereof:

PNM Resources, Inc. became the parent holding company for Public Service Company of New Mexico as of December 31, 2001. Effective as of November 27, 2002, PNM Resources, Inc. assumes the sponsorship of the Plan.

3. Section 2.05 of the Plan is hereby amended in its entirety to read as follows:

2.05 "Company" means PNM Resources, Inc. or any successor thereto, and any company affiliated with PNM Resources, Inc. which adopts the Plan. Any affiliate that adopted the Plan prior to the assumption of the sponsorship of the Plan by the Company, including the Public Service Company of New Mexico, shall continue to participate in the Plan.


4. Section 2.11 of the Plan is hereby amended in its entirety to read as follows:

2.11 "Employees' Retirement Plan" means the PNM Resources, Inc. Employees' Retirement Plan, as amended from time to time.

5. Section 2.20 of the Plan is hereby amended in its entirety to read as follows:

2.20 "Plan" means the PNM Resources, Inc. Accelerated Management Performance Plan as described herein or as hereafter amended.

6. Section 2.23 of the Plan is hereby amended in its entirety to read as follows:

2.23 "Service Bonus Plan" means the PNM Resources, Inc. Service Bonus Plan, as amended from time to time.

7. Section 6.01 is hereby amended by the addition of the following paragraph to be placed at the end thereof to read as follows:

Each affiliate that participates in the Plan shall bear the costs and expenses of providing benefits accrued by its employee-Participants during periods while they are employed by that affiliate. Such costs and expenses shall be allocated among the participating affiliates in accordance with (a) agreements entered into between PNMR and any participating affiliate, or (b) in the absence of such an agreement, procedures adopted by PNMR.

8. The purpose of this Fifth Amendment is to transfer sponsorship of the Plan to PNMR from the PNM. All references to "Public Service Company of New Mexico" are hereby replaced with references to "PNM Resources, Inc.," unless the context (such as discussion of the formation of the Plan) indicates otherwise. Any other provisions of the Plan which are inconsistent with this transfer of sponsorship are hereby amended to the extent necessary to accomplish this transfer.

9. This Fifth Amendment changes the name and sponsorship of the Plan. Any individuals or entities serving as fiduciaries or service providers with respect to the Plan shall continue to serve as such, subject to the provisions of the Plan. Similarly, any policies or procedures previously adopted by the fiduciaries shall continue in full force and effect.

10. PNM Resources, Inc. hereby assumes all duties, obligations, and authority as the sponsor of the Plan. PNM Resources, Inc. does not assume Public Service Company of New Mexico's financial obligation for its share of the costs and expenses of Plan benefits as determined pursuant to Section 6.01 of the Plan.

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11. This Fifth Amendment shall only amend the provisions of the Plan referred to above, and those provisions not amended hereby shall be considered in full force and effect.

IN WITNESS WHEREOF, Public Service Company of New Mexico and PNM Resources, Inc. have caused this Fifth Amendment to be executed as of this 27th day of November, 2002.

PUBLIC SERVICE COMPANY OF NEW MEXICO

By:      /s/ Alice A. Cobb
   ---------------------------------
Its:     Senior Vice President
People Services and Development

ACCEPTED:

PNM RESOURCES, INC.

By:      /s/ Alice A. Cobb
   ---------------------------------
Its:     Senior Vice President
People Services and Development

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EXHIBIT 10.25.1

AMENDMENT
TO THE
SECOND RESTATED AND AMENDED
PUBLIC SERVICE COMPANY OF NEW MEXICO
EXECUTIVE MEDICAL PLAN

THIS AMENDMENT made by the Public Service Company of New Mexico ("PNM") is effective as of January 1, 2002 unless otherwise noted herein.

WHEREAS, PNM maintains the Second Restated and Amended Public Service Company of New Mexico Executive Medical Plan (the "Plan");

WHEREAS, PNM reserved the right to amend the Plan pursuant to Article VIII of the Plan; and

WHEREAS, PNM now desires to amend the Plan to: (i) reflect certain design changes that took effect January 1, 2002 and May 1, 2002; (ii) transfer sponsorship of the Plan from PNM to PNM Resources, Inc. ("PNMR"); (iii) change the name of the Plan to reflect the transfer of sponsorship; and (iv) designate PNM as a participating employer.

NOW, THEREFORE, PNM does hereby amend the Plan as follows:

1. Effective May 1, 2002, Article I (PURPOSE) of the Plan is hereby amended by adding the following to the end thereof:

Effective May 1, 2002, the Plan shall be self-funded rather than fully insured with the benefits provided by Connecticut General Life Insurance Company. This means that benefits will be paid from the Company's general assets. Reimbursements paid from the Company's general assets must be included in a Participant's taxable income for the calendar year in which the Participant receives the reimbursement rather than the calendar year in which the underlying expense is incurred. Amounts paid from the Company's general assets will be grossed-up for taxes using the Participant's assumed tax rate, as determined by the Plan Administrator.

2. The first sentence of Article III (ELIGIBILITY) of the Plan is hereby amended and restated in its entirety to provide as follows:

The Plan shall apply only to an executive employee of the Company whose position with the Company is Vice-President or higher-ranking officer of the Company (a "Participant").

3. The fourth sentence of Article IV (COVERED CHARGES) of the Plan is hereby amended and restated in its entirety to provide as follows:


Notwithstanding the foregoing, Covered Charges shall not include expenses for transportation pursuant to Code Section 213(d)(1)(B) prior to January 1, 2002, for insurance pursuant to Code Sections 213(d)(1)(C) & (D) prior to May 1, 2002, and for lodging pursuant to Code Section 213(d)(2) prior to January 1, 2002.

4. The first sentence of Article V (ANNUAL LIMITATION) of the Plan is hereby amended and restated in its entirety to provide as follows:

The maximum annual amount of Covered Charges incurred during a calendar year subject to reimbursement hereunder shall not exceed three thousand dollars ($3,000) paid to or on behalf of each Participant (the "Annual Limitation").

5. Effective November 30, 2002, sponsorship of the Plan is hereby transferred to PNMR and PNMR, by signing below, hereby assumes all duties, obligations, and authority as the sponsor of the Plan. PNMR does not assume PNM's financial obligation for its share of the costs and expenses of Plan benefits as determined pursuant to Article IV (COVERED CHARGES) of the Plan.

6. Effective November 30, 2002, Article I (PURPOSE) of the Plan is hereby further amended by adding the following to the end thereof:

PNMR became the parent holding company of PNM as of December 31, 2001. Effective as of November 30, 2002, PNMR assumes the sponsorship of the Plan. Any affiliate that adopted the Plan prior to the assumption of the sponsorship of the Plan by PNMR, including PNM, shall continue to participate in the Plan.

7. Effective November 30, 2002, the Plan shall be known as the "PNM RESOURCES,
INC. EXECUTIVE MEDICAL PLAN."

8. Effective November 30, 2002, Article IV (COVERED CHARGES) of the Plan is hereby further amended by adding the following paragraph to the end thereof:

Each affiliate that participates in the Plan shall bear the costs and expenses of providing benefits accrued by its employee-Participants during periods while they are employed by that affiliate. Such costs and expenses shall be allocated among the participating affiliates in accordance with (i) agreements entered into between PNMR and any participating affiliate, or (ii) in the absence of such an agreement, procedures adopted by PNMR.

9. Effective November 30, 2002, all references to "Public Service Company of New Mexico" are hereby replaced with references to "PNM Resources, Inc.," unless the context (such as discussion of the formation of the Plan) indicates otherwise. Any other provisions of the Plan that are inconsistent with this transfer are hereby amended to the extent necessary to accomplish this transfer.

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10. This Amendment shall only amend the provisions of the Plan referred to above, and those provisions not amended hereby shall be considered in full force and effect.

IN WITNESS WHEREOF, Public Service Company of New Mexico has caused this Amendment to be executed as of this 27 day of November, 2002.

PUBLIC SERVICE COMPANY OF NEW MEXICO

By:      /s/ Alice A. Cobb
   ---------------------------------
Its: Senior Vice President

ACCEPTED:

PNM RESOURCES, INC.

By:      /s/ Alice A. Cobb
   ---------------------------------
Its: Senior Vice President

3

EXHIBIT 10.43.1

PUBLIC SERVICE COMPANY OF NEW MEXICO
2002 OFFICER INCENTIVE PLAN

INTRODUCTION

This plan serves as comprehensive single source of information about the Public Service Company of New Mexico ("PNM") annual incentive program for company officers. It describes the objectives of the plan, its various elements, and how they function. If you have questions that are not addressed by this document, please direct them to your manager.

PLAN OBJECTIVES

The plan is designed to:

o Attract, motivate and retain key officer talent in a competitive business environment.

o Link the interests of officers with those of our shareholders through short-term incentives.

o Align total short-term cash compensation opportunities with competitive practices.

o Reinforce a total compensation mix for officers that is risk/reward oriented.

o Customize the plan to meet the needs of specific business segments.

EFFECTIVE DATES

The plan is effective from January 1, 2002 through December 31, 2002 (the "Plan Year"). The Board Governance and Human Resources Committee (the "Committee") of the Board of Directors (the "Board") reserves the right, however, to adjust, amend or suspend the plan at its discretion during the Plan Year.

ADMINISTRATION

o Plan Year Goals

Prior to the beginning of the Plan Year, after considering the recommendations of management, the Committee will approve the corporate goals against which performance will be measured for the Plan Year. The goals will be communicated to all eligible participants as soon thereafter as feasible.

o Incentive Award Approvals and Payout Timing

Shortly after the end of the Plan Year, the Committee or the Board will, in its sole discretion, determine the final performance results that will be used to determine awards, if any. Awards will be distributed by check to eligible participants following such approval during the first quarter following the end of the Plan Year, normally in February.

1

ELIGIBILITY

All officers of the company are eligible to participate in the plan.

o Pro Rata Awards for Partial Service Periods

Pro rata awards for the number of months actively employed at each eligibility level during the Plan Year will be paid to the following participants at the time awards are paid to all participants: (Note: Any month in which a participant is actively on the payroll for at least one day will count as a full month.)

- Participants who are newly hired during the Plan Year.

- Participants who are promoted, transferred or demoted during the Plan Year.

- Participants who are on leave of absence for any full months during the Plan Year.

- Participants who are impacted or leave the company due to retirement during the Plan Year.

- The spouse or legal representative of a deceased participant.

o Forfeiture of Awards

Any participant who terminates employment on or before awards are distributed for the Plan Year for any reason other than those stated above (e.g. voluntary separation, termination for performance or misconduct, even if the terminated participant elects to take retirement) will not be eligible for payment of an award.

o Provisions for a Change in Control

The following provisions will apply should a Change in Control (CIC) of the company occur:

- If neither the plan nor the participant are terminated due to a CIC during the Plan Year, a full year award equal to the higher of 50% of the maximum award opportunity or the award that results from projecting performance results through year-end based on year-to-date performance as of the CIC, if feasible, will be paid to all employees who are still active as of December 31 of the Plan Year.

- If either the plan or the participant is terminated as a result of a CIC during the Protection Period (as defined in the Retention Plans), a pro rata award equal to the higher of 50% of the maximum award opportunity or the award that results from projecting performance results through year-end based on year-to-date performance as of the CIC, if feasible, will be paid upon termination for the number of months worked during the Plan Year.

o Eligible "Base" for Incentive Purposes

For the purpose of incentive calculations, the salary range midpoint effective December 31 of the Plan Year is defined as the participant's eligible base unless the participant has been demoted during the Plan Year. In this event, the officer's award may be prorated based on the period of time worked at each level.

2

AWARD DETERMINATION

Awards may be earned for performance that provides value to our shareholders. The incremental performance needed to fund awards is taken into consideration in establishing performance thresholds and goals under the plan.

o Minimum Performance Threshold

The EPS "Threshold" indicated on the EPS performance scale in Attachment A must be achieved before any payout will be made for the 2002 Plan Year.

o Maximum Award Opportunity

For the 2002 Plan Year, the maximum award opportunities are as follows:

Eligibility Level                  Maximum Award Opportunity
-----------------                  -------------------------
Vice President                           50% of Midpoint
Senior Vice President                    60% of Midpoint
Executive Vice President                 70% of Midpoint
Chairman, President and CEO             100% of Midpoint

PERFORMANCE CRITERIA

The following stand-alone performance criteria are used to determine awards under the plan:

o Team Performance: These goals, which are agreed upon at the beginning of the Plan Year, are identical for all officers. This scale does not provide for interpolation of awards.

o Individual/Unit Performance: These goals, which are agreed upon at the beginning of the Plan Year, are customized by officer and may include measurements such as overall Results Pay Plan Workgroup performance for each officer's area of responsibility, business segment EPS and/or specific individual goals of critical importance that can be linked to one-year performance milestones for the officer. This scale does not provide for interpolation of awards.

o Personal Effectiveness: Each officer's personal effectiveness, as measured against a list of Officer Core Attributes, comprises this measurement. The scale for Personal Effectiveness provides for an award ranging threshold to optimal as indicated on the matrix.

3

EXHIBIT 10.43.2


PNM RESOURCES, INC.
2003 OFFICER INCENTIVE PLAN

INTRODUCTION

This document serves as a comprehensive single source of information about the PNM Resources, Inc. ("PNMR") Officer Incentive Plan. It describes the objectives of the plan, its various elements, and how they function. If you have questions that are not addressed by this document, please direct them to the Compensation Department.

PLAN OBJECTIVES

The plan is designed to motivate and reward participants for achieving and exceeding annual company, business unit and individual goals, and the company-wide Earnings Per Share ("EPS") goal.

EFFECTIVE DATES

The plan is effective from January 1, 2003 through December 31, 2003 (the "Plan Year"). Management reserves the right, however, to adjust, amend or suspend the plan at its discretion during the Plan Year, with the approval of the Board Governance and Human Resources Committee (the "Committee") of the Board of Directors (the "Board").

ADMINISTRATION

o Plan Year Goals

Individual goal sets (e.g. combined company, business unit, and individual) will be established for each Officer. After considering the recommendations of management, the Committee will approve the company-wide EPS goals against which performance will be measured for the Plan Year.

o Incentive Award Approvals and Payout Timing

Shortly after the end of the Plan Year, the Committee or the Board will, in its sole discretion, determine the final performance results which will be used to calculate awards, if any. Awards will be distributed by check to eligible participants following such approval during the first quarter following the end of the Plan Year, typically with the last paycheck in February.

ETHICS

The intent of the plan is to fairly reward performance achievement. Any employee who manipulates or attempts to manipulate the plan for personal gain at the expense of customers, other employees or company objectives will be subject to appropriate disciplinary action, up to and including termination of employment.

1

ELIGIBILITY

All officers of the company are eligible to participate in the plan.

o Pro Rata Awards for Partial Service Periods

Pro rata awards for the number of months actively employed at each eligibility level during the Plan Year will be paid to the following participants at the time awards are paid to all participants: (Note: Any month in which a participant is actively on the payroll for at least one day will count as a full month.)

- Participants who are newly hired during the Plan Year.

- Participants who are promoted, transferred or demoted during the Plan Year.

- Participants who are on leave of absence for any full months during the Plan Year.

- Participants who are impacted or leave the company due to retirement during the Plan Year. (Note: For purposes of the plan, "retirement" means termination of employment with the company and all affiliates after the employee has satisfied the age and service requirements for early or normal retirement under the Employee Retirement Plan.)

- Participants who die during the Plan Year, in which case the award will be paid to the spouse of a married participant or the legal representative of an unmarried participant.

o Forfeiture of Awards

Any participant who terminates employment on or before awards are distributed for the Plan Year for any reason other than death, impaction or retirement (e.g., voluntary separation, termination for performance or misconduct - even if the terminated participant elects to take retirement) will not be eligible for payment of an award.

o Provisions for a Change in Control

Please refer to Executive Retention Plan for additional information.

o Eligible Base for Incentive Purposes

For the purpose of incentive calculations, the applicable salary grade midpoint is the participant's salary grade midpoint effective December 31 of the Plan Year unless the participant has been demoted during the Plan Year. In this event, the participant's salary grade midpoint may be prorated based on the period of time worked at each level.

AWARD DETERMINATION

Awards may be earned for performance that provides additional value to our shareholders. The incremental performance needed to fund awards is taken into consideration in establishing performance thresholds and goals under the plan.

o Performance Thresholds

In order to be eligible for incentive awards, the following performance threshold must be met for 2003:

2

- Overall combined company, business unit, and individual goal performance that at least achieves the threshold performance level. If this performance threshold is not met, no award will be paid for the Plan Year.

In order to be eligible for the award enhancement, the following performance threshold must be met for 2003:

- Company-wide EPS that at least achieves $1.80. If this performance threshold is not met, no award enhancement will be applied.

o Combined Company, Business Unit, and Individual Performance Award Opportunity

For the 2003 Plan Year, the combined company, business unit, and individual performance award opportunities are as follows:

------------------------------- ---------------------------------------------
    Award Eligibility Level                Individual Goal Set
------------------------------- ---------------------------------------------
                                Threshold*       Stretch*           Optimal*
------------------------------- ---------- ---------------------- -----------
Vice-President                     4.0%            7.0%              10.0%
------------------------------- ---------- ---------------------- -----------
Senior Vice-President              4.8%            8.4%              12.0%
------------------------------- ---------- ---------------------- -----------
Executive Vice-President           5.6%            9.8%              14.0%
------------------------------- ---------- ---------------------- -----------
Chairman, President, and CEO       8.0%            14.0%             20.0%
------------------------------- ---------- ---------------------- -----------

* Award calculated as a percentage of salary grade midpoint

o Earnings Per Share (EPS) Award Enhancement

For the 2003 Plan Year, the EPS award enhancement opportunities are as follows:

---------------------------- ---------------------- --------------------------
EPS Threshold Target = $1.80  EPS = $1.81 to $2.04  EPS Optimal Target = $2.05
---------------------------- ---------------------- --------------------------
Workgroup Performance Award    Workgroup Award is      Workgroup Performance
      is enhanced 2x           enhanced between 2x      Award is enhanced a
                                   and 5x using             maximum of 5x
                                  interpolation
---------------------------- ---------------------- --------------------------

For this plan, EPS is defined as net income related to running the business (excluding certain extraordinary items or events that result in windfalls or penalties which are not in keeping with the spirit of the plan) divided by the number of shares of PNMR common stock outstanding.

o Award Calculation

Combined company, business unit, and individual goal performance that meets or exceeds the threshold target level will be eligible for an award. The amount of each participant's award is determined by the participant's eligibility level and the level of combined company, business unit, and individual goal performance in the "Combined Company, Business Unit, and Individual Performance Award Opportunity" table above.

Company EPS performance that meets or exceeds the threshold target will serve as an enhancement to the award paid for workgroup performance. As identified in the "EPS Award Enhancement" table above, the award enhancement will be a minimum of 2x at the EPS threshold target, a maximum of 5x at the EPS optimal target, and interpolated between the EPS threshold and optimal targets.

The resulting percent is multiplied by the participant's eligible salary grade midpoint to determine the amount of the participant's award.

For Example: Assume that overall Workgroup results are at the optimal performance level and company-wide EPS performance is $1.93. A participant who is eligible for an award at the Vice-President eligibility level would receive an award of 35% of salary grade midpoint for the Plan Year. That is, workgroup optimal performance resulting in an award of 10%, which is then enhanced 3.5x for EPS performance. If the participant's salary grade midpoint is $160,000 the award would be $56,000 ($160,000 x 35%).

3

EXHIBIT 10.45.4

FOURTH AMENDMENT
TO THE PUBLIC SERVICE COMPANY OF NEW MEXICO
SERVICE BONUS PLAN

THIS FOURTH AMENDMENT made by the Public Service Company of New Mexico ("PNM") is effective as of November 27, 2002.

WHEREAS, PNM adopted the Public Service Company of New Mexico Service Bonus Plan (the "Plan") as of October 23, 1984 to provide supplemental income benefits for certain executives who have achieved maximum performance credits under the Accelerated Management Performance Plan;

WHEREAS, the Plan has been amended three times, most recently by an amendment effective on December 7, 1998;

WHEREAS, PNM reserved the right to amend the Plan pursuant to Section 9.01 of the Plan; and

WHEREAS, PNM now desires to amend the Plan to: (i) change the name of the Plan, (ii) change the sponsor of the Plan to PNM Resources, Inc. ("PNMR"), and (iii) designate PNM as a participating employer.

NOW, THEREFORE, PNM does hereby amend the Plan as follows:

1. The name of the Plan is hereby amended to read as follows:

PNM RESOURCES, INC. SERVICE BONUS PLAN

2. Section 1.01 of the Plan is hereby amended by the addition of the following paragraph to be placed at the end thereof:

PNM Resources, Inc. became the parent holding company for Public Service Company of New Mexico as of December 31, 2001. Effective as of November 27, 2002, PNM Resources, Inc. assumes the sponsorship of the Plan.

3. Section 2.01 of the Plan is hereby amended in its entirety to read as follows:

2.01 "Accelerated Management Performance Plan" means the PNM Resources, Inc. Accelerated Management Performance Plan, as amended from time to time.

4. Section 2.08 of the Plan is hereby amended in its entirety to read as follows:

2.08 "Company" means PNM Resources, Inc. or any successor thereto, and any company affiliated with PNMR that adopts the Plan. Any affiliate that adopted the Plan prior to including Public Service Company of New Mexico, shall continue to participate in the Plan.

1

5. Section 2.13 of the Plan is hereby amended in its entirety to read as follows:

2.13 "Employees' Retirement Plan" means the PNM Resources, Inc. Employees' Retirement Plan, as amended from time to time.

6. Section 2.20 of the Plan is hereby amended in its entirety to read as follows:

2.20 "Plan" means the PNM Resources, Inc. Service Bonus Plan as described herein or as hereafter amended.

7. Section 2.24 of the Plan is hereby amended in its entirety to read as follows:

2.24 "Service Bonus Plan" means the PNM Resources, Inc. Service Bonus Plan described herein, or as amended from time to time.

8. Section 6.01 of the Plan is hereby amended by the addition of the following paragraph to be placed at the end thereof:

Each affiliate that participates in the Plan shall bear the costs and expenses of providing benefits accrued by its employee-Participants during periods while they are employed by that affiliate. Such costs and expenses shall be allocated among the participating affiliates in accordance with (a) agreements entered into between PNM Resources, Inc. and any participating affiliate, or (b) in the absence of such an agreement, procedures adopted by PNM Resources, Inc.

9. Section 6.04 of the Plan is hereby amended in its entirety to read as follows:

6.04 Change in Control. Upon a Change in Control, as defined in the First Restated and Amended Executive Retention Plan effective December 7, 1998, and incorporated herein by reference, the Company shall sufficiently fund the Public Service Company of New Mexico and Paragon Resources, Inc. Deferred Compensation Trust Agreement (the "Rabbi Trust") to provide in full any benefits accrued under this Plan as of the date of the occurrence of the Change in Control.

10. The purpose of this Fourth Amendment is to transfer sponsorship of the Plan to PNM Resources, Inc. from the Public Service Company of New Mexico. All references to "Public Service Company of New Mexico" are hereby replaced with references to "PNM Resources, Inc.," unless the context (such as discussion of the formation of the Plan) indicates otherwise. Any other provisions of the Plan which are inconsistent with this transfer of sponsorship are hereby amended to the extent necessary to accomplish this transfer.

2

11. PNM Resources, Inc. hereby assumes all duties, obligations, and authority as the sponsor of the Plan. PNM Resources, Inc. does not assume Public Service Company of New Mexico's financial obligation for its share of the costs and expenses of Plan benefits as determined pursuant to Section _____ of the Plan.

12. This Fourth Amendment changes the name and sponsorship of the Plan. Any individuals or entities serving as fiduciaries or service providers with respect to the Plan shall continue to serve as such, subject to the provisions of the Plan. Similarly, any policies or procedures previously adopted by the fiduciaries shall continue in full force and effect.

13. This Fourth Amendment shall only amend the provisions of the Plan referenced above, and those provisions not amended hereby shall be considered in full force and effect.

IN WITNESS WHEREOF, Public Service Company of New Mexico and PNM Resources, Inc. have caused this Fourth Amendment to be executed as of this 27th day of November, 2002.

PUBLIC SERVICE COMPANY OF NEW MEXICO

By:      /s/ Alice A. Cobb
   ---------------------------------
Its: Senior Vice President
     People Services and Development

ACCEPTED:

PNM RESOURCES, INC.

By:      /s/ Alice A. Cobb
   ---------------------------------
Its: Senior Vice President
     People Services and Development

3

EXHIBIT 10.48.2

SECOND AMENDMENT
TO THE
PUBLIC SERVICE COMPANY OF NEW MEXICO
OBRA '93 RETIREMENT PLAN

THIS SECOND AMENDMENT made by the Public Service Company of New Mexico ("PNM") is effective as of November 27, 2002.

WHEREAS, PNM adopted the Public Service Company of New Mexico OBRA '93 Retirement Plan (the "Plan") as of November 15, 1993 to provide nonqualified retirement benefits for certain key employees;

WHEREAS, the Plan has been amended once, effective as of December 7, 1998;

WHEREAS, PNM reserved the right to amend the Plan pursuant to Article V of the Plan; and

WHEREAS, PNM now desires to amend the Plan to: (i) change the name of the Plan, (ii) change the sponsor of the Plan to PNM Resources, Inc. ("PNMR"), and (iii) designate PNM as a participating employer.

NOW, THEREFORE, PNM hereby amends the Plan as follows:

1. The name of the Plan is hereby amended to read as follows:

PNM RESOURCES, INC. OBRA '93 RETIREMENT PLAN

2. The introductory paragraphs of the Plan (being those paragraphs that precede Article I) are hereby amended by the addition of the following paragraph to be placed at the end thereof:

PNM Resources, Inc. became the parent holding company for Public Service Company of New Mexico as of December 31, 2001. Effective as of November 27, 2002, PNM Resources, Inc. assumes the sponsorship of the Plan. Any affiliate that adopted the Plan prior to the assumption of the sponsorship of the Plan by the PNM Resources, Inc., including Public Service Company of New Mexico, shall continue to participate in the Plan.

3. Section 4.02 is hereby amended by adding a new subsection (f) to read as follows:

(f) Each employer that participates in the Plan shall bear the costs and expenses of providing benefits accrued by its employee-Participants during periods while they are employed by that employer. Such costs and expenses shall be allocated among the participating employers in accordance with (i) agreements entered into between the Company and any participating employer, or (ii) in the absence of such an agreement, procedures adopted by the Company.

1

4. The purpose of this Second Amendment is to transfer sponsorship of the Plan to PNMR from PNM. All references to "Public Service Company of New Mexico" or the "Company" are hereby replaced with references to "PNM Resources, Inc.," unless the context (such as discussion of the formation of the Plan) indicates otherwise. Any other provisions of the Plan which are inconsistent with this transfer of sponsorship are hereby amended to the extent necessary to accomplish this transfer.

5. This Second Amendment changes the name and sponsorship of the Plan. Any individuals or entities serving as fiduciaries or service providers with respect to the Plan shall continue to serve as such, subject to the provisions of the Plan. Similarly, any policies or procedures previously adopted by the fiduciaries shall continue in full force and effect.

6. PNMR hereby assumes all duties, obligations, and authority as the sponsor of the Plan. PNMR does not assume PNM's financial obligation for its share of the costs and expenses of Plan benefits as determined pursuant to Section 4.02(f) of the Plan.

7. This Second Amendment shall only amend the provisions of the Plan referenced above, and those provisions not amended hereby shall be considered in full force and effect.

IN WITNESS WHEREOF, Public Service Company of New Mexico and PNM Resources, Inc. have caused this Second Amendment to be executed as of this 27th day of November, 2002.

PUBLIC SERVICE COMPANY OF NEW MEXICO

By: /s/ Alice A. Cobb
   ---------------------------------
Its: Senior Vice President
     People Services and Development

ACCEPTED:

PNM RESOURCES, INC.

By: /s/ Alice A. Cobb
Its: Senior Vice President
     People Services and Development

2

EXHIBIT 10.50.1

FIRST AMENDMENT TO THE
PUBLIC SERVICE COMPANY OF NEW MEXICO
SECTION 415 PLAN

THIS FIRST AMENDMENT TO THE PUBLIC SERVICE COMPANY OF NEW MEXICO
SECTION 415 PLAN is effective the 7th day of December 1998 by the Public Service Company of New Mexico, a New Mexico corporation ("PNM" or the "Company").

WHEREAS, the Company established the Public Service Company of New Mexico Section 415 Plan (the "Plan") effective January 1, 1994.

WHEREAS, under Section 6.03, the Company reserved the right at any time to amend the Plan;

WHEREAS, on December 7, 1998, the Compensation and Human Resources Committee of the PNM Board of Directors approved certain benefits upon a Change in Control (as defined in the First Restated and Amended Executive Retention Plan) and authorized certain amendments to affected plans, including this Plan; and

WHEREAS, the Company desires to amend this Plan to incorporate the approved Change in Control benefits to provide full and sufficient funding of the Public Service Company of New Mexico and Paragon Resources, Inc. Deferred Compensation Trust Agreement (the "Rabbi Trust") for any obligations or benefits accrued as of the date of the occurrence of a Change in Control.

NOW THEREFORE, the Company hereby amends the Plan as follows:

ITEM 1. Article V, Source of Benefit Payments, shall be amended to add
a new Section 5.02, as follows:


5.02 Change in Control. Upon a Change in Control, as defined in the First Restated and Amended Executive Retention Plan effective December 7, 1998, and incorporated herein by reference, the Company shall sufficiently fund the Public Service Company of New Mexico and Paragon Resources, Inc. Deferred Compensation Trust Agreement (the "Rabbi Trust") to provide in full for any benefits accrued under this Plan as of the date of the occurrence of the Change in Control.

ITEM 2. Except as herein above amended, the Company hereby readopts and
redeclares each and every other provision of the Plan.

IN WITNESS WHEREOF, Public Service Company of New Mexico caused this First Amendment to the Public Service Company of New Mexico Section 415 Plan to be executed by its authorized officers effective as of the date and year first above written.

PUBLIC SERVICE COMPANY OF NEW MEXICO

Date:  December 7, 1998                 By       /s/ BENJAMIN F. MONTOYA
                                           -------------------------------------
                                           BENJAMIN F. MONTOYA
                                           President and Chief Executive Officer


SECOND AMENDMENT
TO THE PUBLIC SERVICE COMPANY OF NEW MEXICO
SECTION 415 PLAN

THIS SECOND AMENDMENT TO THE PUBLIC SERVICE COMPANY OF NEW MEXICO
SECTION 415 PLAN (the "Plan"), is made by the Public Service Company of New Mexico, a New Mexico corporation ("PNM" or the "Company"), to be effective August 7, 1999.

WHEREAS, the Company adopted the Public Service Company of New Mexico
Section 415 Plan effective January 1, 1994.

WHEREAS, the Compensation and Human Resources Committee (the "Committee") of the PNM Board of Directors adopted the First Amendment to the Plan, effective December 7, 1998;

WHEREAS, under Section 6.03 of the Plan, the Company reserved the right at any time to amend the Plan;

WHEREAS, the Company has established subsidiaries and affiliates, and intends to transfer or has transferred current Participants of the Plan to the subsidiaries and affiliates; and

WHEREAS, the Company desires to amend this Plan to ensure that such transferred Participants remain eligible for benefits under the Plan.

NOW THEREFORE, the Plan is hereby amended, as follows:

ITEM 1. Section 1.01, Purpose, shall be modified as follows:

1.01 Purpose. The Purpose of the Section 415 Plan is to provide for the payment of supplemental retirement benefits to employees of the Company, its subsidiaries and affiliates, or its holding company or subsidiaries of the holding company, whose retirement benefits, under the Public Service Company of New Mexico Employees' Retirement Plan (the "Retirement Plan"), as restated effective January 1, 1997, have been reduced as required by Section 415 of the Internal Revenue Code of 1986, as amended (the "Code"), and applicable regulations and rulings promulgated thereunder. Code Section 415 requires that qualified defined benefit retirement plans, such as the Retirement Plan, limit the amount payable, in any one year, to a retired Participant. The Code
Section 415 limitations reduce the retirement benefits otherwise due a Participant notwithstanding that such benefits were previously accrued and vested pursuant to qualified retirement plans.

1

ITEM 2. The first paragraph of Section 2.01 Participation, shall be
modified as follows:

2.01 Participation. An employee of the Company, or any subsidiary, affiliate or holding company of the Company, or subsidiary of the holding company, who satisfies the following requirements shall be entitled to participate in the Section 415 Plan, and shall hereinafter be referred to as a "Participant." The transfer of a Participant to an affiliate shall not be deemed a termination of employment with the Company and shall not affect any Participant's rights to receive benefits hereunder.

ITEM 3. Except as herein above amended, the Company hereby readopts and
redeclares each and every other provision of the Plan.

IN WITNESS WHEREOF, Public Service Company of New Mexico caused this Second Amendment to the Public Service Company of New Mexico Section 415 Plan to be executed by its authorized officers effective as of the date and year first above written.

PUBLIC SERVICE COMPANY OF NEW MEXICO

By    /s/ ARTHUR P. ARMANO
   ---------------------------------------
   ARTHUR P. ARMANO
   Director, Personnel Services

2

THIRD AMENDMENT
TO THE
PUBLIC SERVICE COMPANY OF NEW MEXICO
SECTION 415 PLAN

THIS THIRD AMENDMENT made by the Public Service Company of New Mexico ("PNM") is effective as of November 27, 2002.

WHEREAS, PNM adopted the Public Service Company of New Mexico Section 415 Plan (the "Plan") as of January 1, 1994, to provide supplemental retirement benefits for certain employees;

WHEREAS, the Plan has been amended twice, the most recent amendment being effective as of August 7, 1999;

WHEREAS, PNM reserved the right to amend the Plan pursuant to Section 6.03 of the Plan; and

WHEREAS, PNM now desires to amend the Plan to: (i) change the name of the Plan; (ii) change the sponsor of the Plan to PNM Resources, Inc. ("PNMR"); and (iii) designate PNM as a participating employer.

NOW, THEREFORE, PNM hereby amends the Plan as follows:

1. The name of the Plan is hereby amended to read as follows:

PNM RESOURCES, INC. SECTION 415 PLAN

2. The introductory paragraph of the Plan is hereby amended by the addition of the following paragraph to be placed at the end thereof:

PNM Resources, Inc. became the parent holding company for Public Service Company of New Mexico as of December 31, 2001. Effective as of November 27, 2002, PNM Resources, Inc. assumes the sponsorship of the Plan. Any affiliate that adopted the Plan prior to the assumption of the sponsorship of the Plan by the PNM Resources, Inc., including Public Service Company of New Mexico, shall continue to participate in the Plan.

3. Section 1.01 of the Plan is hereby amended in its entirety to read as follows:

1.01 Purpose. The purpose of the Section 415 Plan is to provide for the payment of supplemental retirement benefits to employees of the Company, and other subsidiaries and affiliates of the Company, whose retirement benefits under the PNM Resources, Inc. Employees' Retirement Plan (the "Retirement Plan") have been reduced as required by Section 415 of the Internal Revenue Code of 1986, as amended (the "Code"), and applicable regulations and rulings promulgated

1

thereunder. Code Section 415 requires that qualified defined benefit retirement plans, such as the Retirement Plan, limit the amount payable, in any one year, to a retired Participant. The Code Section 415 limitations reduce the retirement benefits otherwise due a Participant notwithstanding that such benefits were previously accrued and vested pursuant to qualified retirement plans.

4. Article V of the Plan is hereby amended by the addition of a new Section 5.02 to read as follows:

5.02 Allocation Among Affiliates. Each affiliate that participates in the Plan shall bear the costs and expenses of providing benefits accrued by its employee-Participants during periods while they are employed by that affiliate. Such costs and expenses shall be allocated among the participating affiliates in accordance with (a) agreements entered into between the Company and any participating affiliate, or (b) in the absence of such an agreement, procedures adopted by the Company.

5. The purpose of this Third Amendment is to transfer sponsorship of the Plan to PNMR from PNM. All references to "Public Service Company of New Mexico" or the "Company" are hereby replaced with references to "PNM Resources, Inc.," unless the context (such as discussion of the formation of the Plan) indicates otherwise. Any other provisions of the Plan which are inconsistent with this transfer of sponsorship are hereby amended to the extent necessary to accomplish this transfer.

6. PNMR hereby assumes all duties, obligations, and authority as the sponsor of the Plan. PNMR does not assume PNM's financial obligation for its share of the costs and expenses of Plan benefits as determined pursuant to
Section 5.02 of the Plan.

7. This Third Amendment changes the name and sponsorship of the Plan. Any individuals or entities serving as fiduciaries or service providers with respect to the Plan shall continue to serve as such, subject to the provisions of the Plan. Similarly, any policies or procedures previously adopted by the fiduciaries shall continue in full force and effect.

8. This Third Amendment shall only amend the provisions of the Plan referenced above, and those provisions not amended hereby shall be considered in full force and effect.

2

IN WITNESS WHEREOF, Public Service Company of New Mexico and PNM Resources, Inc. have caused this Third Amendment to be executed as of this 27th day of November, 2002.

PUBLIC SERVICE COMPANY OF NEW MEXICO

By:  /s/ Alice A. Cobb
   ----------------------------------------
Its: Senior Vice President
     People Services and Development

ACCEPTED:

PNM RESOURCES, INC.

By: /s/ Alice A. Cobb
   ----------------------------------------
Its: Senior Vice President
People Services and Development

3

EXHIBIT 10.51.1

FIRST AMENDMENT
TO THE
PUBLIC SERVICE COMPANY OF NEW MEXICO
FIRST RESTATED AND AMENDED
EXECUTIVE RETENTION PLAN

THIS FIRST AMENDMENT made by the Public Service Company of New Mexico ("PNM") is effective as of November 27, 2002.

WHEREAS, PNM adopted the Public Service Company of New Mexico Executive Retention Plan (the "Plan") as of January 1, 1992 to provide certain benefits for its executives;

WHEREAS, the Plan has been amended and restated effective December 7, 1998;

WHEREAS, PNM reserved the right to amend the Plan pursuant to Article IX of the Plan; and

WHEREAS, PNM now desires to amend the Plan to: (i) change the name of the Plan, (ii) change the sponsor of the Plan to PNM Resources, Inc. ("PNMR"), and (iii) designate PNM as a participating employer.

NOW, THEREFORE, PNM does hereby amend the Plan as follows:

NOW, THEREFORE, Public Service Company of New Mexico does hereby amend the Plan as follows:

1. The name of the Plan is hereby amended to read as follows:

PNM RESOURCES, INC.
FIRST RESTATED AND AMENDED
EXECUTIVE RETENTION PLAN

2. The introductory paragraphs of the Plan (being those paragraphs that precede Article I) are hereby amended by the addition of the following paragraph to be placed at the end thereof:

PNM Resources, Inc. became the parent holding company for Public Service Company of New Mexico as of December 31, 2001. Effective as of November 27, 2002, PNM Resources, Inc. assumes the sponsorship of the Plan. Any affiliate that adopted the Plan prior to the assumption of the sponsorship of the Plan by the PNM Resources, Inc., including Public Service Company of New Mexico, shall continue to participate in the Plan.


3. Section 2.8 is hereby amended in its entirety to read as follows:

2.8 "Company" shall mean PNM Resources, Inc. unless the context, such as discussion of the formation of the Plan, clearly indicates otherwise, in which case "Company" can also mean Public Service Company of New Mexico. As used in this Plan, "Company" shall also mean any successor to its assets, as described in Article II, Section 2.5.3, and 2.5.4, that assumes and agrees to perform the Company's obligations hereunder, by operation of law or otherwise. "Company" may also include any holding company owning the Company or subsidiary of such holding company, depending on the context of the reference within this Plan.

4. Article VI is hereby amended by adding a new Section 6.4 to read as follows:
6.4 Allocation Among Affiliates. Each employer that participates in the Plan shall bear the costs and expenses of providing benefits accrued by its employee-Participants during periods while they are employed by that employer. Such costs and expenses shall be allocated among the participating employers in accordance with (i) agreements entered into between the Company and any participating employer, or (ii) in the absence of such an agreement, procedures adopted by the Company.

5. The purpose of this First Amendment is to transfer sponsorship of the Plan to PNMR from PNM. All references to "Public Service Company of New Mexico" or the "Company" are hereby replaced with references to "PNM Resources, Inc.," unless the context (such as discussion of the formation of the Plan) indicates otherwise. Any other provisions of the Plan which are inconsistent with this transfer of sponsorship are hereby amended to the extent necessary to accomplish this transfer.

6. This First Amendment changes the name and sponsorship of the Plan. Any individuals or entities serving as fiduciaries or service providers with respect to the Plan shall continue to serve as such, subject to the provisions of the Plan. Similarly, any policies or procedures previously adopted by the fiduciaries shall continue in full force and effect.

7. PNMR hereby assumes all duties, obligations, and authority as the sponsor of the Plan. PNMR does not assume PNM's financial obligation for its share of the costs and expenses of Plan benefits as determined pursuant to Section 6.4 of the Plan.

8. This First Amendment shall only amend the provisions of the Plan referenced above, and those provisions not amended hereby shall be considered in full force and effect.

2

IN WITNESS WHEREOF, Public Service Company of New Mexico has caused this First Amendment to be executed as of this 27th day of November, 2002.

PUBLIC SERVICE COMPANY OF NEW MEXICO

By:      /s/ Alice A. Cobb
   -------------------------------------
Its:     Senior Vice President
         People Services and Development

ACCEPTED:

PNM RESOURCES, INC.

By:      /s/ Alice A. Cobb
   -------------------------------------
Its:     Senior Vice President
         People Services and Development

3

EXHIBIT 10.52

PNM RESOURCES, INC.
EXECUTIVE SPENDING ACCOUNT PLAN

Effective December 1, 2002


TABLE OF CONTENTS

Page

INTRODUCTION................................................................1

DEFINED TERMS...............................................................1

GENERAL INFORMATION ABOUT THE PLAN..........................................5

ELIGIBILITY AND PARTICIPATION REQUIREMENTS..................................6

SUMMARY OF PLAN BENEFITS....................................................8

HOW THE PLAN IS ADMINISTERED...............................................10

CLAIMS PROCEDURES..........................................................10

AMENDMENT OR TERMINATION OF THE PLAN.......................................14

NO CONTRACT OF EMPLOYMENT..................................................14

-i-

ARTICLE 1
INTRODUCTION

Public Service Company of New Mexico ("PNM") adopted the "Amended and Restated Medical Reimbursement Plan of Public Service Company of New Mexico" (the "MERP") effective January 1, 1980. The MERP was amended and restated in its entirety effective September 1, 1991 at which time it was renamed the "Second Restated and Amended Public Service Company of New Mexico Executive Medical Plan." Effective November 30, 2002, PNM transferred sponsorship of the MERP to PNM Resources, Inc. ("PNMR"). Effective January 1, 2002, PNMR initiated an Executive Spending Account (the "ESA").

From March 1, 2001 through April 30, 2002, the MERP was fully insured and the benefits were provided by Connecticut General Life Insurance Company ("CIGNA"). Effective May 1, 2002, a decision was made that benefits under the MERP should again be provided on a self-funded basis. The benefits provided under the ESA are, and always have been, self-funded.

By this document, effective December 1, 2002, PNMR hereby merges the MERP with and into the ESA and amends and restates both plans in the form of this combined program, such program to be known as the "PNM Resources, Inc. Executive Spending Account Plan" (the "Plan").

PNMR maintains the Plan to provide a select group of Company executives with additional remuneration in the form of reimbursements for: (i) medical benefits beyond the medical benefits available to the executives under any medical insurance under which they are covered; and (2) other expenses such as income tax preparation costs, costs for estate planning and financial counseling services, and insurance premiums for health, accident, disability, life, dependent life, long-term care, home, auto and personal umbrella insurance. The benefits provided under the Plan are paid from the general assets of PNMR and those of its affiliates that have adopted the Plan with each Company bearing the costs and expenses of providing benefits accrued by its Employee-Participants during periods while they are employed by that Company. Such costs and expenses are allocated among the Companies in accordance with (i) agreements entered into between PNMR and any participating affiliate, or (ii) in the absence of such an agreement, procedures adopted by PNMR. Because benefits are paid from the general assets of the Company, pursuant to Department of Labor regulation
Section 2520.104-24 the Plan is exempt from most of the reporting and disclosure requirements of Part 1 of Title I of ERISA, including the requirement to provide a summary plan description and the requirement to file a Form 5500 - Annual Report.

ARTICLE 2
DEFINED TERMS

Capitalized terms used in the Plan have the following meanings:

Assumed Tax Rate: The tax rate that the Plan Administrator will use to gross-up amounts reimbursed under Tier A of the Plan. Participants will be notified of their Assumed Tax Rate each Paycheck Year.

1

Code:                      The Internal Revenue Code of 1986, as amended.

Company:                   PNM Resources, Inc. ("PNMR") and any affiliate that
                           has adopted the Plan with the approval of PNMR. Any
                           affiliate that adopted the Plan prior to the
                           assumption of the sponsorship of the Plan by PNMR,
                           including Public Service Company of New Mexico, shall
                           continue to participate in the Plan.

Covered Expense:           Tier A Covered Expenses and Tier B Covered Expenses.


Dependent:                 A Participant's "Dependents" as defined by the
                           Medical Plan who are eligible to be enrolled in the
                           Medical Plan regardless of whether they are actually
                           enrolled in that plan.

Effective Date:            December 1, 2002.

Employee:                  A full-time employee of the Company scheduled to work
                           at least 32 hours per week, or a regular part-time or
                           job share employee scheduled to work at least 20
                           hours per week. Employee does not include: leased
                           employees or workers; independent contractors,
                           consultants or similar self-employed workers;
                           temporary employees or workers; seasonal employees or
                           workers, other contingent workers, or any employee of
                           any affiliate or related entity unless specifically
                           approved by the Company.

ERISA:                     The Employee Retirement Income Security Act of 1974,
                           as amended.

HIPAA:                     The Health Insurance Portability and Accountability
                           Act of 1996, as amended.

Medical Insurance:         Medical insurance coverage under any of the
                           following: (1) The Public Service Company of New
                           Mexico Benefits My Way Plan, Program 2, Medical Plan,
                           effective January 1, 2002, as amended from time to
                           time, or any successor plan; (2) any other employer
                           maintained medical plan covering the Participant and
                           his or her Dependants; and (3) any other medical
                           insurance covering the participant and/or his or her
                           Dependents.

NMHPA:                     The Newborns' and Mothers' Health Protection Act of
                           1996, as amended.

Participant:               An Employee who is eligible to participate in this
                           Plan pursuant to Article 4.

Paycheck Year:             The Paycheck Year commences on the third
                           Saturday before the final paycheck for a calendar
                           year is paid and ends on the third Friday before the
                           final paycheck for the next calendar year is paid.
                           For example, the final paycheck for the 2002 calendar
                           year will be issued on Friday, December 27, 2002.
                           This means that the 2003 Paycheck Year will commence
                           on December 7, 2002 and end on December 5, 2003.

2

Plan:                      The PNM Resources, Inc. Executive Spending Account
                           Plan, as set forth in this document.

Plan Administrator:        PNMR.

Plan Sponsor:              PNMR.

PNMR:                      PNM Resources, Inc.

Qualifying Event:          A Participant's termination of employment, reduction
                           in hours, divorce, legal separation, death or
                           becoming eligible for Medicare, and a child ceasing
                           to meet the Plan's definition of Dependent.

Tier A:                    The portion of the Plan under which Tier A Covered
                           Expenses are reimbursed. With very few exceptions,
                           expenses that were formerly reimbursed under the MERP
                           are, as of the Effective Date, reimbursed under Tier
                           A.

Tier A Benefit Limit:      The maximum amount for which you and your Dependents,
                           together, may seek reimbursement each Paycheck Year
                           for Tier A Covered Expenses. As of the Effective
                           Date, the Tier A Benefit Limit is $3,000 per Paycheck
                           Year. Any portion of the Tier A Benefit Limit that
                           remains unused at the end of a Paycheck Year may not
                           be carried over to the following Paycheck Year. Any
                           amounts reimbursed by CIGNA under the MERP from
                           January 1, 2002 through April 30, 2002 (while the
                           MERP was fully-insured), will reduce the Tier A
                           Benefit Limit for the remainder of the 2002 Paycheck
                           Year by a corresponding amount.

Tier A Covered Expenses:   Expenses  incurred by a Participant or Dependent
                           during the current or preceding Paycheck Year, while
                           covered by the Plan, for medical care as defined in
                           Section 213(d) of the Code to the extent that no
                           benefits are payable for such medical care under the
                           Participant's Medical Insurance. By way of example,
                           and not limitation, medical care, dental care, vision
                           care, premiums for medical care and qualified
                           long-term care (whether paid on a pre-tax or
                           after-tax basis), transportation primarily for and
                           essential to medical care, and amounts paid for
                           lodging (not lavish or extraordinary under the
                           circumstances) while away from home primarily for and
                           essential to medical care would all be treated as
                           Tier A Covered Expenses.

                           A Tier A Covered Expense is "incurred" when the
                           underlying medical care is provided, regardless of
                           when you are billed or pay for such medical care,
                           unless the medical care for which you are seeking
                           reimbursement is for insurance premiums covering
                           medical care or qualified long-term care, in which
                           case such expense is "incurred" on the date on which
                           you are billed for the premium.

                                       3

Tier B:                    The portion of the Plan under which Tier B Covered
                           Expenses are reimbursed. With very few exceptions,
                           expenses that were formerly reimbursed under the ESA
                           are, as of the Effective Date, reimbursed under Tier
                           B.

Tier B Benefit Limit:      The maximum amount for which you and your Dependents,
                           together, may seek reimbursement each Paycheck Year
                           for Tier B Covered Expenses. Shortly before each
                           Paycheck Year, you will be notified of your Tier B
                           Benefit Limit for the Paycheck Year. Any portion of
                           the Tier B Benefit Limit that remains unused at the
                           end of a Paycheck Year may not be carried over to the
                           following Paycheck Year. Any amounts reimbursed by
                           the Company under the ESA from January 1, 2002
                           through April 30, 2002, will reduce the Tier B
                           Benefit Limit for the remainder of the 2002 Paycheck
                           Year by a corresponding amount.

Tier B Covered Expenses:   Expenses  incurred  by the  Participant  or a
                           Dependent during the current or preceding Paycheck
                           Year, while covered by the Plan, for any of the
                           following: (1) income tax preparation; (2) estate
                           planning (including preparation of wills and trusts);
                           (3) financial counseling, but excluding brokerage
                           fees or commissions; (4) financial management
                           services (this would include, for example, the
                           services provided by a management firm that manages
                           your real estate investments); (5) premiums covering
                           the Participant and his or her Dependents for
                           accident, disability, life, dependent life, long-term
                           care and or supplemental insurance (similar to
                           AFLAIC), whether paid for by the Participant as a
                           private party or deducted from the Participant's
                           salary under a PNM benefit program; (6) premiums for
                           home, auto or personal liability umbrella insurance;
                           or (7) expenses that would qualify as a Tier A
                           Covered Expense but for the fact that the Tier A
                           Benefit Limit has already been exceeded for the
                           Paycheck Year.

                           A Tier B Covered Expense is "incurred" as of the date
                           on which you are billed for the underlying expense;
                           provided, however, that if the expense qualifies as a
                           Tier A Covered Expense, but for the fact that the
                           Tier A Benefit Limit has already been exceeded for
                           the Paycheck Year, the expense is "incurred" when the
                           underlying medical care is provided, regardless of
                           when you are billed or pay for such medical care,
                           unless the medical care for which you are seeking
                           reimbursement is for insurance premiums covering
                           medical care or qualified long-term care, in which
                           case such expense is "incurred" on the date on which
                           you are billed for the premium.

WHCRA:                     The Women's Health and Cancer Rights Act of 1998,
                           as amended.

4

ARTICLE 3
GENERAL INFORMATION ABOUT THE PLAN

Plan Name:                 PNM Resources, Inc. Executive Spending Account Plan.

Plan Year:                 January 1 through December 31

Plan Number:               601

Original Effective Date:   The MERP was originally  effective  January 1, 1980.
                           The ESA was first effective January 1, 2002.

Funding Medium:            The Plan is  self-funded.  This means that the
                           Company pays benefits out of its general assets.
                           Participants are not required to pay a premium in
                           order to participate in the Plan.

Plan Sponsor:              PNM Resources, Inc.
                           Alvarado Square, Mail Stop 3101
                           Albuquerque, NM  87158
                           (505) 241-2700

Plan Sponsor's Employer    85-0468296
Identification Number:

Plan Administrator &       PNM Resources, Inc.
Named Fiduciary:           Alvarado Square, Mail Stop 3101
                           Albuquerque, NM  87158
                           (505) 241-2700
                           Attention: Manager-Employee Benefits Department

                           The Plan is administered by the Company or its
                           designee.

Agent for Service of       Patrick Ortiz, General Counsel
Legal Process:             Public Service Company of New Mexico
                           Alvarado Square, Mail Stop 2822
                           Albuquerque, NM  87158
                           (505) 241-2700

Applicable Law:            The validity,  interpretation,  construction and
                           performance of the Plan shall be governed by the laws
                           of the State of New Mexico, unless preempted by
                           ERISA.

5

ARTICLE 4
ELIGIBILITY AND PARTICIPATION REQUIREMENTS

Eligibility:               You are  eligible to  participate  in the Plan if you
                           are an Employee of the Company and you are a
                           vice-president or higher-ranking officer of the
                           Company. Your spouse and "Dependents," as defined in
                           Article 2 are eligible to participate in the Plan if
                           you are.

Termination of             Your  participation  in the Plan  terminates  as of
Participation:             the  earliest  of:  (1) the date you terminate
                           employment with the Company; (2) the date you cease
                           to be a vice-president or higher ranking officer of
                           the Company; (3) the date your coverage under all
                           other Medical Insurance ceases; or (4) the date the
                           Plan is terminated.

                           Coverage for your Dependents (including your
                           spouse) stops when your coverage stops. Their
                           coverage will also stop if they cease being your
                           Dependent.

COBRA:                     If coverage for you or your Dependents (including
                           your spouse) ceases because of certain "Qualifying
                           Events," specified in a federal law called COBRA,
                           then you or your Dependents may have the right to
                           purchase continuing coverage under the Plan for a
                           limited period of time. As permitted by law, the
                           Company may impose an administrative fee (usually
                           2%) for this coverage. This right to continue
                           coverage only applies to the portions of the Plan
                           that reimburse medical care expenses.

Effect of Termination      If a Participant or Dependent's participation in the
of Participation on        Plan terminates, any Tier A or  Tier B Covered
Reimbursements:            Expenses incurred by the Participant or Dependent
                           before his or her participation terminated will be
                           eligible for reimbursement even though such
                           reimbursement is not requested or processed before
                           such termination date. Except as required by COBRA,
                           Tier A and Tier B Covered Expenses incurred after
                           such termination date will not be eligible for
                           reimbursement even though the Participant may not
                           have used all or some portion of his or her Tier A or
                           Tier B Benefit Limits. The following examples
                           illustrate how these rules operate:

                           Example 1: Assume that a Participant terminates
                           employment on June 30, and as of such date has been
                           reimbursed $2,500 under Tier A. Before terminating
                           employment, while still covered by the Plan, the
                           Participant incurred an additional $750 of Tier A
                           Covered Expenses. The Participant is entitled to
                           receive a Tier A reimbursement in the amount of
                           $500.

                                       6

                           Example 2: Assume that a Participant ceases to be a
                           vice president or higher-ranking officer on
                           September 30, and as of such date has been
                           reimbursed $500 under Tier A. After changing
                           employment status, while no longer covered by the
                           Plan, the Participant incurs an additional $1,750
                           of Tier A Covered Expenses. The Participant is not
                           entitled to receive a Tier A or Tier B
                           reimbursement for the amounts incurred after her
                           participation is terminated.

Effect of Promotion        If a Participant is promoted during a Paycheck Year
or Demotion on             and such promotion causes the  Participant to be
Reimbursements:            subject to a higher Tier B Benefit Limit, Tier B
                           Covered Expenses incurred before the increased limit
                           takes effect will be eligible for reimbursement as
                           long as they were incurred while the Participant was
                           covered by the Plan. If a Participant is demoted
                           during a Paycheck Year and such demotion causes the
                           Participant to be subject to a lower Tier B Benefit
                           Limit, Tier B Covered Expenses incurred before the
                           decreased limit takes effect will be subject to
                           reimbursement as long as they were incurred while the
                           Participant was covered by the Plan. The following
                           examples illustrate how these rules operate:

                           Example 1: Assume that a Participant is promoted
                           from vice president to senior vice president on
                           October 1st. Assume further that as vice president,
                           the Participant's Tier B Benefit Limit was $7,000
                           and as senior vice president, the Participant's
                           Tier B Benefit Limit is $12,000. Before being
                           promoted, and while covered by the Plan, the
                           Participant incurred $13,000 of Tier B Covered
                           Expenses but has only been reimbursed for $7,000.
                           As of October 1st, the Participant is entitled to
                           be reimbursed an additional $5,000 because of the
                           $12,000 Tier B Benefit Limit to which the
                           Participant is now subject.

                           Example 2: Assume that a Participant is demoted
                           from senior vice president to vice president on
                           July 1st. Assume further that as senior vice
                           president, the Participant's Tier B Benefit Limit
                           was $12,000 and as vice president, the
                           Participant's Tier B Benefit Limit is $7,000.
                           Before being demoted, and while covered by the
                           Plan, the Participant incurred $11,000 of Tier B
                           Covered Expenses but has only been reimbursed for
                           $9,000. As of October 1st, the Participant is
                           entitled to be reimbursed for the $2,000 of Tier B
                           Covered Expenses that were incurred before October
                           1st, even though the Participant is now subject to
                           a $7,000 Tier B Benefit Limit.

                                       7

                           Example 3: Assume that a Participant is demoted
                           from senior vice president to vice president on
                           November 1st. Assume further that as senior vice
                           president, the Participant's Tier B Benefit Limit
                           was $12,000 and as vice president, the
                           Participant's Tier B Benefit Limit is $7,000.
                           Before being demoted, and while covered by the
                           Plan, the Participant incurred $4,000 of Tier B
                           Covered Expenses and had been reimbursed for the
                           full $4,000. After being demoted, the Participant
                           incurs an additional $8,000 of Tier B Covered
                           Expenses. The Participant is entitled to receive a
                           Tier B reimbursement of $3,000 because as of
                           November 1st, the Participant is now subject to a
                           $7,000 Tier B Benefit Limit.

ARTICLE 5
SUMMARY OF PLAN BENEFITS

Two Tier Benefit           The Plan has two tiers, Tier A and Tier B.
Structure:
                           If an expense qualifies as a Tier A Covered Expense,
                           the Company will reimburse you for 100% of the Tier A
                           Covered Expense under Tier A of the Plan up to the
                           Tier A Benefit Limit (i.e., $3,000 for you and your
                           Dependents, together, per Paycheck Year). Once you
                           and your Dependents, together, reach the $3,000 Tier
                           A Benefit Limit, no benefits will be paid to you
                           under Tier A for the remainder of the Paycheck Year.
                           Before you submit a claim for reimbursement under
                           Tier A, you must first submit it for payment under
                           your Medical Insurance.

                           If an expense qualifies as a Tier B Covered Expense,
                           the Company will pay you for 100% of the Tier B
                           Covered Expense under Tier B of the Plan up to the
                           Tier B Benefit Limit. Once you and your Dependents,
                           together, reach the Tier B Benefit Limit, no benefits
                           will be paid to you under Tier B for the remainder of
                           the Paycheck Year. If an expense qualifies as a Tier
                           A Covered Expense but for the fact that the Tier A
                           Benefit Limit has been exceeded, the Plan
                           Administrator will automatically process the expense
                           under Tier B, and reimbursement will be made under
                           Tier B, unless the Tier B Benefit Limit has been
                           exceeded.

Tax Treatment of           The  expenses  reimbursed  under Tiers A and B must
Benefits:                  be included  in the  Participant's  taxable income
                           for the calendar year in which the Participant
                           receives the reimbursement, rather than the calendar
                           year in which the underlying expense is incurred.
                           Reimbursements approved by the Plan Administrator
                           will be added to your regular paycheck unless the
                           reimbursement is for a Tier A Covered Expense, in
                           which case it is processed as a separate check
                           through payroll. Notwithstanding the foregoing,
                           effective January 1, 2003, all reimbursements
                           approved by the Plan Administrator will be processed
                           as a separate check through payroll rather than being
                           added to your regular paycheck. In all cases the
                           additional income will be reflected on your W-2 for
                           the calendar year in which the additional income is
                           paid to you. Prior to May 1, 2002, the benefits

                                       8

                           provided under the MERP were not includable in the
                           Participant's taxable income because the benefits
                           provided under the MERP were fully insured by CIGNA.
                           Accordingly, any reimbursements received from CIGNA
                           are not includable in the Participant's taxable
                           income and are not subject to the gross-up rule
                           described below.

Gross-Up of Tier A         Any expense that is  reimbursed  under Tier A of the
Covered Expenses:          Plan will be grossed-up  for taxes,  using the
                           Participant's Assumed Tax Rate. For example, if a
                           Participant receives the maximum reimbursement of
                           $3,000 under Tier A, and the Participant's Assumed
                           Tax Rate is 40%, the Participant will be reimbursed
                           in the amount of $5,000. After paying taxes on the
                           $5,000, the Participant will be left with $3,000
                           (i.e., $5,000 x (1-.40) = $3,000). Expenses
                           reimbursed under Tier B will not be grossed up even
                           though such amounts must be included in the
                           Participant's taxable income.

Compliance with            The Plan will provide benefits in accordance with the
Federal Laws:              applicable requirements of federal laws, such as
                           COBRA, HIPAA, NMHPA and the WHRCA. For example, did
                           you know that the Plan, as required by the WHCRA
                           provides benefits for mastectomy-related services
                           including reconstruction and surgery to achieve
                           symmetry between breasts, prostheses, and
                           complications from mastectomy (including lymphedema)?
                           Call the Plan Administrator for more information.

Qualified Medical          The Plan will also provide benefits to an Employee's
Child Support              non-custodial Dependent child as required by any
Orders:                    qualified medical child support order, or "QMCSO"
                           (as defined in ERISA Section 609(a)). The Plan has
                           detailed procedures for determining whether an order
                           qualifies as a QMCSO. Participants and beneficiaries
                           can obtain, without charge, a copy of such procedures
                           from the Plan Administrator.

Benefits for               The Plan will  provide  benefits to  Dependent
Adopted Children:          children placed with an Employee for adoption under
                           the same terms and conditions as apply in the case of
                           Dependent children who are natural children, in
                           accordance with ERISA Section 609(c).

Special Rights             The Plan may not, under Federal law, restrict
Upon Childbirth:           benefits for any hospital length of stay in
                           connection with childbirth for the mother or newborn
                           child to less than 48 hours following a normal
                           vaginal delivery, or less than 96 hours following a
                           cesarean section. However, Federal law generally does
                           not prohibit the mother's or newborn's attending
                           provider, after consulting with the mother, from
                           discharging the mother or her newborn earlier than
                           the above periods. In any case, the Plan may not,
                           under Federal law, require that a provider obtain
                           authorization from the Plan for prescribing a length
                           of stay not in excess of the above periods.

9

ARTICLE 6
HOW THE PLAN IS ADMINISTERED

Plan Administration: The Plan is administered by the Plan Administrator.
The Manager of the Employee Benefits Department of the Company is the person who has been designated to act on behalf of the Plan Administrator.

The principal duty of the Plan Administrator is to see that the Plan is carried out, in accordance with

                           its terms, for the exclusive benefit of persons
                           entitled to participate in the Plan without
                           discrimination among them. The administrative duties
                           of the Plan Administrator include, but are not
                           limited to, interpreting the Plan, and prescribing
                           applicable procedures. The Plan Administrator is also
                           responsible for determining eligibility for and the
                           amount of any benefits payable under the Plan and
                           prescribing claims procedures to be followed and the
                           claims forms to be used by employees for making
                           claims under the Plan. The Plan Administrator also
                           has the authority to require Employees to furnish it
                           with such information as it determines necessary for
                           the proper administration of the Plan.

                           The Plan Administrator may delegate any of these
                           administrative duties among one or more persons or
                           entities, provided that such delegation is in
                           writing, expressly identifies the delegate(s) and
                           expressly describes the nature and scope of the
                           delegated responsibility.

                           If you have any questions regarding the Plan, please
                           contact the Plan Administrator.

Discretionary              The  Plan   Administrator   shall  have  the
Authority to Act:          discretionary authority to perform its administrative
                           responsibilities described in this Plan as necessary
                           or appropriate to enable the Plan Administrator to
                           properly carry out such responsibilities. The
                           decisions of the Plan Administrator upon all matters
                           within the scope of the Plan Administrator's
                           respective authority shall be binding and conclusive
                           upon all persons.

ARTICLE 7

                                Claims Procedures

Reimbursement             Requests: The Plan Administrator is responsible for
                          evaluating all reimbursement requests under the Plan.
                          You must submit all reimbursement requests to the Plan
                          Administrator in accordance with its procedures;
                          provided, however, that each December (or more
                          frequently if you request), the Benefits Department
                          will calculate the insurance deductions that have been
                          taken from your pay during the Paycheck Year, and will
                          submit these for reimbursement on your behalf to the
                          Plan Administrator.

                                       10

                          Reimbursement requests should be submitted as soon as
                          possible after the underlying expense is "incurred,"
                          although, for repetitive expenses, you may want to
                          submit your request when you have other expenses, or
                          at some fixed interval, such as every three or six
                          months. See the definitions of "Tier A Covered
                          Expense" and "Tier B Covered Expense" to determine
                          when an expense is incurred. Please keep in mind that
                          to be reimbursed, an expense must be submitted for
                          reimbursement no later than the end of the Paycheck
                          Year following the Paycheck Year in which the expense
                          was incurred.

                          In order to count against the Tier A or Tier B Benefit
                          Limit for a given Paycheck Year, a properly documented
                          reimbursement request must be sent to the Plan
                          Administrator on or before the last day of such
                          Paycheck Year. Any properly submitted reimbursement
                          requests submitted to the Plan Administrator during a
                          Paycheck Year will be taxable income to the
                          Participant for the calendar year that commences
                          during the Paycheck Year. For example, the 2003
                          Paycheck Year will commence on December 7, 2002 and
                          end on December 5, 2003. Thus any requests submitted
                          from December 7, 2002 through December 5, 2003 will be
                          taxable income to the Participant for the 2003
                          calendar year.

                          To facilitate recordkeeping and reimbursements,
                          expenses submitted at least 3 days before pay period
                          end will be processed and reimbursed during that same
                          payroll period. Expenses submitted after such deadline
                          will be processed and paid during the following
                          payroll period.

                          If a reimbursement request is for medical care, you
                          must first submit the claim for payment to your
                          Medical Insurance, and submit a copy of the resulting
                          explanation of benefits ("EOB") to the Plan
                          Administrator as documentation of the expense. On all
                          reimbursement requests, be sure to include the name of
                          the provider, the nature of the service rendered, and
                          your name on the receipt or invoice. If the claim is
                          in the category of health (other than for prescription
                          drugs), the ICD-9 code assigned by the provider will
                          suffice in place of the nature of the service
                          rendered. Cancelled checks and credit card receipts
                          cannot be used as the sole documentation of an expense
                          submitted for reimbursement.

Dissatisfaction with      If  a  you  are  dissatisfied  with  the
Decision:                 determination of your benefits, eligibility,
                          participation or any other right or interest under
                          this Plan, you may file a written statement setting
                          forth the basis of the claim with the Plan
                          Administrator in a manner prescribed by the Plan
                          Administrator. In connection with the determination
                          of a claim, or in connection with the review of a
                          denied claim, you may examine this Plan and any other
                          pertinent documents generally available to
                          Participants relating to the claim and you may submit
                          written comments, documents, records and other
                          information relating to the claim for benefits.

11

Notice of Decision:       A written notice of the disposition of any such claim
                          will be furnished to you within 90 days after the
                          claim is filed with the Plan Administrator, provided
                          that the Plan Administrator may have an additional
                          period of up to 90 days to decide the claim if it
                          determines that special circumstances require an
                          extension of time to decide the claim and it advises
                          you in writing of the need for an extension
                          (including an explanation of the special
                          circumstances requiring the extension) and the date
                          on which it expects to decide the claim.

Content of Notice:        The notice of disposition of a claim shall set forth:

                          o    the specific reasons for denial of the claim;

                          o    reference to the specific Plan provisions upon
                               which the determination is based;

                          o    a  description  of any  additional  material or
                               information  necessary for you to perfect  the
                               claim and an  explanation  of why such  material
                               or  information  is necessary; and

                          o    an explanation of the Plan's appeal procedure
                               and an explanation of the time limits
                               applicable to the Plan's appeal procedures,
                               including a statement of your right to bring
                               a civil action under Section 502(a) of ERISA,
                               following an adverse benefit determination on
                               review.

Appeal of Denied Claim:   Within 60 days after receiving the written notice of
                          the Plan Administrator's disposition of the claim,
                          your, or your duly authorized representative, may
                          request in writing that the Plan Administrator review
                          the denied claim. You may submit a written statement
                          of your claim (including any written comments,
                          documents, records and other information relating to
                          the claim) and the reasons for granting the claim.
                          The Plan Administrator shall have the right to
                          request of and receive from a claimant such
                          additional information, documents or other evidence
                          as the Plan Administrator may reasonably require. If
                          you do not request a review of the denied claim
                          within 60 days after receiving written notice of the
                          Plan Administrator's disposition of the claim, you
                          will be deemed to have accepted the Plan
                          Administrator's written disposition, unless you have
                          been physically or mentally incapacitated so as to be
                          unable to request review within the 60-day period.

                          Upon request and free of charge, you will be provided
                          reasonable access to, and copies of, all documents,
                          records, and other information relevant to your claim
                          for benefits, with such relevance to be determined as
                          set forth below under "Relevance of Documents."

                          The review shall take into account all comments,
                          documents, records and other information submitted by
                          you relating to the claim, without regard to whether
                          such documents, records or other information were
                          submitted or considered in the initial benefit
                          determination.

                                       12

Decision on Appeal:       A decision on appeal shall be rendered, in writing,
                          by the Plan Administrator ordinarily not later than
                          60 days after you request review of a denied claim,
                          and a written copy of such decision shall be
                          delivered to you. If special circumstances require an
                          extension of the ordinary period, the Plan
                          Administrator will notify you of the extension with
                          such notice containing an explanation of the special
                          circumstances requiring the extension and the date by
                          which the Plan Administrator expects to render a
                          decision. Any such extension will not extend beyond
                          60 days after the end of the ordinary period.

The denial notice shall set forth:

                          o   the specific reasons for denial of the claim;

                          o   reference to the specific Plan provisions upon
                              which the denial is based;

                          o   a statement that you are is entitled to
                              receive, upon request and free of charge,
                              reasonable access to, and copies of, all
                              documents, records, and other information
                              relevant to the your claim for benefits; and

                          o   a statement of your right to bring a civil action
                              under Section 502(a) of ERISA.

Relevance of              For purpose of this Article 7, documents, records,
Documents:                or other information shall be considered "relevant"
                          to your claim for benefits if such documents, records
                          or other information:

                          o   were relied upon in making the benefit
                              determination;

                          o   were submitted, considered, or generated in
                              the course of making the benefit determination,
                              without regard to whether such documents, records
                              or other information were relied upon in making
                              the benefit determination; or

                          o   demonstrate compliance with the administrative
                              processes and safeguards required by this
                              Article 7 regarding the making of the benefit
                              determination.

Decisions Final and       To the extent  permitted  by law, a decision on review
Procedures Mandatory:     by the Plan Administrator shall be binding and
                          conclusive upon all persons whomsoever. To the extent
                          permitted by law, completion of the claims procedures
                          described in this Article shall be a mandatory
                          precondition that must be complied with prior to
                          commencement of a legal or equitable action in
                          connection with the Plan by a person claiming rights
                          under the Plan or by another person claiming rights
                          through such a person. The Plan Administrator may, in
                          its sole discretion, waive these procedures as a
                          mandatory precondition to such an action.

13

ARTICLE 8
AMENDMENT OR TERMINATION OF THE PLAN

PNMR, as Plan Sponsor, has the right to amend or terminate the Plan at any time. The Plan may be amended or terminated by a written instrument duly adopted by PNMR or any of its delegates.

ARTICLE 9
NO CONTRACT OF EMPLOYMENT

The Plan is not intended to be, and may not be construed as constituting, a contract or other arrangement between you and the Company to the effect that you will be employed for any specific period of time.

IN WITNESS WHEREOF, PNM Resources, Inc. has caused this Plan to be executed as of this 27 day of November, 2002.

PNM RESOURCES, INC.

By:      /s/ Alice A. Cobb
Its: Senior Vice President

14

Exhibit 10.72

195,000,000

CREDIT AGREEMENT

among

PUBLIC SERVICE COMPANY OF NEW MEXICO
as Borrower,

THE LENDERS IDENTIFIED HEREIN,

BANK OF AMERICA, N.A.,
as Administrative Agent

WACHOVIA BANK, NATIONAL ASSOCIATION,
as Syndication Agent

AND

FLEET NATIONAL BANK
as Documentation Agent

DATED AS OF DECEMBER 19, 2002

BANC OF AMERICA SECURITIES LLC,
as Sole Lead Arranger and Sole Book Manager


                                TABLE OF CONTENTS
                                -----------------


SECTION 1  DEFINITIONS AND ACCOUNTING TERMS...................................1
         1.1      Definitions.................................................1
                  -----------
         1.2      Computation of Time Periods and Other
                  Definitional Provisions....................................16
                  -----------------------
         1.3      Accounting Terms/Calculation of
                  Financial Covenants........................................16
                  -------------------
         1.4      Time.......................................................16
                  ----
         1.5      Rounding of Financial Covenants............................16
                  -------------------------------
         1.6      References to Agreements and Requirement of Laws...........17
                  ------------------------------------------------

SECTION 2  CREDIT FACILITY...................................................17
         2.1      Revolving Loans............................................17
                  ---------------
         2.2      Letter of Credit Subfacility...............................18
                  ----------------------------
         2.3      Continuations and Conversions..............................25
                  -----------------------------
         2.4      Minimum Amounts............................................26
                  ---------------

SECTION 3  GENERAL PROVISIONS APPLICABLE TO REVOLVING LOANS..................26
         3.1      Interest...................................................26
                  --------
         3.2      Payments Generally.........................................27
                  ------------------
         3.3      Prepayments................................................28
                  -----------
         3.4      Fees.......................................................29
                  ----
         3.5      Payment in full at Maturity................................29
                  ---------------------------
         3.6      Computations of Interest and Fees..........................30
                  ---------------------------------
         3.7      Pro Rata Treatment.........................................30
                  ------------------
         3.8      Sharing of Payments........................................31
                  -------------------
         3.9      Capital Adequacy...........................................32
                  ----------------
         3.10     Eurodollar Provisions......................................32
                  ---------------------
         3.11     Illegality.................................................32
                  ----------
         3.12     Requirements of Law; Reserves on Eurodollar Loans..........33
                  -------------------------------------------------
         3.13     Taxes......................................................33
                  -----
         3.14     Compensation...............................................36
                  ------------
         3.15     Determination and Survival of Provisions...................36
                  ----------------------------------------

SECTION 4  CONDITIONS PRECEDENT TO CLOSING...................................37
         4.1      Closing Conditions.........................................37
                  ------------------

SECTION 5  CONDITIONS TO ALL EXTENSIONS OF CREDIT............................39
         5.1      Funding Requirements.......................................39
                  --------------------

SECTION 6  REPRESENTATIONS AND WARRANTIES....................................40
         6.1      Organization and Good Standing.............................40
                  ------------------------------
         6.2      Due Authorization..........................................40
                  -----------------
         6.3      No Conflicts...............................................40
                  ------------
         6.4      Consents...................................................40
                  --------
         6.5      Enforceable Obligations....................................41
                  -----------------------
         6.6      Financial Condition........................................41
                  -------------------
         6.7      No Material Change.........................................41
                  ------------------
         6.8      No Default.................................................41
                  ----------

                                       i

         6.9      Litigation.................................................41
                  ----------
         6.10     Taxes......................................................41
                  -----
         6.11     Compliance with Law........................................42
                  -------------------
         6.12     ERISA......................................................42
                  -----
         6.13     Use of Proceeds; Margin Stock..............................43
                  -----------------------------
         6.14     Government Regulation......................................43
                  ---------------------
         6.15     Solvency...................................................43
                  --------
         6.16     Disclosure.................................................43
                  ----------
         6.17     Environmental Matters......................................44
                  ---------------------
         6.18     Material Leases............................................44
                  ---------------
         6.19     Material Lease Interest Payments and Discount Rate.........44
                  --------------------------------------------------

SECTION 7  AFFIRMATIVE COVENANTS.............................................44
           ---------------------
         7.1      Information Covenants......................................44
                  ---------------------
         7.2      Financial Covenants........................................46
                  -------------------
         7.3      Preservation of Existence and Franchises...................46
                  ----------------------------------------
         7.4      Books and Records..........................................47
                  -----------------
         7.5      Compliance with Law........................................47
                  -------------------
         7.6      Payment of Taxes and Other Indebtedness....................47
                  ---------------------------------------
         7.7      Insurance..................................................47
                  ---------
         7.8      Performance of Obligations.................................47
                  --------------------------
         7.9      Use of Proceeds............................................48
                  ---------------
         7.10     Audits/Inspections.........................................48
                  ------------------

SECTION 8  NEGATIVE COVENANTS................................................48
           ------------------
         8.1      Nature of Business.........................................48
                  ------------------
         8.2      Consolidation and Merger...................................48
                  ------------------------
         8.3      Sale or Lease of Assets....................................48
                  -----------------------
         8.4      Affiliate Transactions.....................................49
                  ----------------------
         8.5      Liens......................................................49
                  -----
         8.6      Accounting Changes.........................................50
                  ------------------

SECTION 9  EVENTS OF DEFAULT.................................................50
           -----------------
         9.1      Events of Default..........................................50
                  -----------------
         9.2      Acceleration; Remedies.....................................52
                  ----------------------
         9.3      Allocation of Payments After Event of Default..............53
                  ---------------------------------------------

SECTION 10  AGENCY PROVISIONS................................................54
         10.1     Appointment and Authorization of Administrative Agent......54
                  -----------------------------------------------------
         10.2     Delegation of Duties.......................................55
                  --------------------
         10.3     Liability of Administrative Agent..........................55
                  ---------------------------------
         10.4     Reliance by Administrative Agent...........................55
                  --------------------------------
         10.5     Notice of Default..........................................56
                  -----------------
         10.6     Credit Decision; Disclosure of Information by the
                  Administrative Agent.......................................56
                  --------------------
         10.7     Indemnification of Administrative Agent....................57
                  ---------------------------------------
         10.8     Administrative Agent in its Individual Capacity............57
                  -----------------------------------------------
         10.9     Successor Administrative Agent.............................58
                  ------------------------------
         10.10    Administrative Agent May File Proofs of Claim..............58
                  ---------------------------------------------
         10.11    Other Agents; Arrangers and Managers.......................59
                  ------------------------------------

                                       ii

SECTION 11  MISCELLANEOUS....................................................59
         11.1     Notices and Other Communications; Facsimile Copies.........59
                  --------------------------------------------------
         11.2     Right of Set-Off...........................................60
                  ----------------
         11.3     Successors and Assigns.....................................61
                  ----------------------
         11.4     No Waiver; Remedies Cumulative.............................64
                  ------------------------------
         11.5     Attorney Costs, Expenses, Taxes and Indemnification
                  by Borrower................................................64
                  -----------
         11.6     Amendments, Waivers and Consents...........................66
                  --------------------------------
         11.7     Counterparts...............................................67
                  ------------
         11.8     Headings...................................................67
                  --------
         11.9     Survival of Indemnification and Representations
                  and Warranties.............................................67
                  --------------
         11.10    Governing Law; Venue; Jurisdiction.........................67
                  ----------------------------------
         11.11    Waiver of Jury Trial; Waiver of Consequential Damages......68
                  -----------------------------------------------------
         11.12    Severability...............................................68
                  ------------
         11.13    Further Assurances.........................................68
                  ------------------
         11.14    Confidentiality............................................68
                  ---------------
         11.15    Entirety...................................................69
                  --------
         11.16    Binding Effect; Continuing Agreement.......................69
                  ------------------------------------
         11.17    Regulatory Statement.......................................69
                  --------------------


                                       ii

SCHEDULES
---------

Schedule 1.1(a)               Pro Rata Shares
Schedule 1.1(c)               Existing Letters of Credit
Schedule 6.18                 Material Leases
Schedule 6.19                 Material Lease Interest Payments and Discount Rate
Schedule 11.1                 Notices


EXHIBITS
--------

Exhibit 2.1(b)                Form of Notice of Borrowing
Exhibit 2.1(e)                Form of Revolving Note
Exhibit 2.3                   Form of Notice of Continuation/Conversion
Exhibit 7.1(c)                Form of Compliance Certificate
Exhibit 11.3(b)               Form of Assignment and Assumption

iv

CREDIT AGREEMENT

THIS CREDIT AGREEMENT (this "Credit Agreement") is entered into as of December 19, 2002 among PUBLIC SERVICE COMPANY OF NEW MEXICO, a New Mexico corporation, as Borrower, the Lenders and BANK OF AMERICA, N.A., as Administrative Agent and L/C Issuer.

RECITALS

WHEREAS, the Borrower has requested the Lenders to provide a senior credit facility to the Borrower in an aggregate principal amount of $195,000,000; and

WHEREAS, the Lenders party hereto have agreed to make the requested senior credit facility available to the Borrower on the terms and conditions hereinafter set forth.

NOW, THEREFORE, IN CONSIDERATION of the premises and other good and valuable consideration, the receipt and sufficiency of which is hereby acknowledged, the parties hereto agree as follows:

SECTION 1

DEFINITIONS AND ACCOUNTING TERMS

1.1 Definitions.

The following terms shall have the meanings specified herein unless the context otherwise requires. Defined terms herein shall include in the singular number the plural and in the plural the singular:

"Adjusted Eurodollar Rate" means the Eurodollar Rate plus the Applicable Percentage.

"Administrative Agent" means Bank of America or any successor administrative agent appointed pursuant to Section 10.9.

"Administrative Agent's Office" means the Administrative Agent's address and, as appropriate, account as set forth on Schedule 11.1 or such other address or account with as the Administrative Agent may from time to time notify the Borrower and the Lenders.

"Administrative Fees" has the meaning set forth in Section 3.4(d).

"Administrative Questionnaire" means an Administrative Questionnaire in a form supplied by the Administrative Agent.

"Affiliate" means, with respect to any Person, any other Person directly or indirectly controlling (including but not limited to


all directors and officers of such Person), controlled by or under direct or indirect common control with such Person. A Person shall be deemed to control a corporation if such Person possesses, directly or indirectly, the power (a) to vote 10% or more of the securities having ordinary voting power for the election of directors of such corporation or (b) to direct or cause direction of the management and policies of such corporation, whether through the ownership of voting securities, by contract or otherwise.

"Agent-Related Persons" means the Administrative Agent, together with its Affiliates and the officers, directors, employees, agents and attorneys-in-fact of the Administrative Agent and its Affiliates.

"Applicable Percentage" means, for Eurodollar Loans, L/C Fees, Commitment Fees and Utilization Fees, the appropriate applicable percentages, in each case, corresponding to the Debt Rating in effect as of the most recent Calculation Date as shown below:

------- --------------- ------------------ ----------------- -----------------
                             Applicable
                           Percentage for      Applicable        Applicable
Pricing                   Eurodollar Rate    Percentage for    Percentage for
 Level    Debt Rating   Loans and L/C Fees  Commitment Fees   Utilization Fees
------- --------------- ------------------ ----------------- -----------------
        greater than equal
   I    to BBB+/Baa1           .875%              .10%             .125%

------- --------------- ------------------ ----------------- -----------------
  II      BBB/Baa2             1.00%              .15%             .125%
------- --------------- ------------------ ----------------- -----------------
 III      BBB-/Baa3           1.125%              .20%             .125%
------- --------------- ------------------ ----------------- -----------------
  IV      BB+/Ba1              1.25%              .25%             .250%
------- --------------- ------------------ ----------------- -----------------
        less than
   V      BB+/Ba1             .50%              .30%             .500%
------- --------------- ------------------ ----------------- -----------------

The Applicable Percentages shall be determined and adjusted on the date (each a "Calculation Date") one Business Day after the date on which the Borrower's Debt Rating is upgraded or downgraded in a manner which requires a change in the then applicable Pricing Level set forth above. If at any time there is a split in the Borrower's Debt Ratings between S&P and Moody's, the Applicable Percentages shall be determined by the lower of the two Debt Ratings (i.e. the higher pricing); provided that if the two Debt Ratings are more than one level apart, the Applicable Percentage shall be based on the Debt Rating which is one level higher than the lower rating. Each Applicable Percentage shall be effective from one Calculation Date until the next Calculation Date. Any adjustment in the Applicable Percentage shall be applicable to all existing Eurodollar Loans as well as any new Eurodollar Loans made.

"Approved Fund" means any Fund that is administered or managed by (a) a Lender, (b) an Affiliate of a Lender or (c) an entity or an Affiliate of an entity that administers or manages a Lender.

"Arranger" means Banc of America Securities LLC, together with its successors and/or assigns.

"Assignment and Assumption" means an Assignment and Assumption substantially in the form of Exhibit 11.3(b).

2

"Authorized Officer" means any of the president, chief executive officer, chief financial officer or treasurer of the Borrower.

"Bank of America" means Bank of America, N.A., together with its successors and/or assigns.

"Bankruptcy Code" means the Bankruptcy Code in Title 11 of the United States Code, as amended, modified, succeeded or replaced from time to time.

"Base Rate" means for any day a fluctuating rate per annum equal to the higher of (a) the Federal Funds Rate plus 1/2 of 1% and
(b) the rate of interest in effect for such day as publicly announced from time to time by Bank of America as its "prime rate" (the "Prime Rate"). The Prime Rate is a rate set by Bank of America based upon various factors including Bank of America's costs and desired return, general economic conditions and other factors, and is used as a reference point for pricing some loans, which may be priced at, above, or below such announced rate. Any change in such rate announced by Bank of America shall take effect at the opening of business on the day specified in the public announcement of such change.

"Base Rate Loan" means any Revolving Loan bearing interest at a rate determined by reference to the Base Rate.

"Borrower" means Public Service Company of New Mexico, a New Mexico corporation, together with its successors and permitted assigns.

"Borrower Obligations" means, without duplication, all of the obligations of the Borrower to the Lenders and the Administrative Agent, whenever arising, under this Credit Agreement, the Revolving Notes, or any of the other Credit Documents.

"Borrowing" means a borrowing consisting of simultaneous Revolving Loans of the same Type and, in the case of Eurodollar Loans, having the same Interest Period made by each of the Lenders pursuant to
Section 2.1.

"Business Day" means any day other than a Saturday, a Sunday, a legal holiday or a day on which banking institutions are authorized or required by Law or other governmental action to close in New York, New York or Charlotte, North Carolina; provided that in the case of Eurodollar Loans such day is also a day on which dealings are conducted by and between banks in the London interbank market.

"Capital Stock" means (a) in the case of a corporation, all classes of capital stock of such corporation, (b) in the case of a partnership, partnership interests (whether general or limited), (c) in the case of a limited liability company, membership interests and (d) any other interest or participation that confers on a Person the right to receive a share of the profits and losses of, or distributions of assets of, the issuing Person; including, in each case, all warrants, rights or options to purchase any of the foregoing.

3

"Cash Collateralize" means to pledge and deposit with or deliver to the Administrative Agent, for the benefit of the L/C Issuer and the Lenders, as collateral for the L/C Obligations, cash or deposit account balances pursuant to documentation in form and substance satisfactory to the Administrative Agent and the L/C Issuer.

"Change of Control" means the failure of PNM Resources, Inc., a New Mexico corporation, to own and control less than 100% of the Voting Stock of the Borrower.

"Closing Date" means the date of this Credit Agreement, which is the first date all the conditions precedent in Section 5.1 are satisfied or waived in accordance with Section 5.1.

"Code" means the Internal Revenue Code of 1986 and the rules and regulations promulgated thereunder, as amended, modified, succeeded or replaced from time to time.

"Commitment" means, as to each Lender, its obligation to (a) make Revolving Loans to the Borrower pursuant to Section 2.1 and (b) fund or purchase Participation Interests in L/C Obligations pursuant to
Section 2.2, in an aggregate principal amount at any one time outstanding not to exceed such Lender's Pro Rata Share of the Revolving Committed Amount as set forth opposite such Lender's name on Schedule 1.1(a) or in the Assignment and Assumption pursuant to which such Lender becomes a party hereto, as applicable, as such amount may be adjusted from time to time in accordance with this Credit Agreement.

"Compensation Period" has the meaning set forth in Section 3.2(c)(ii).

"Compliance Certificate" means a fully completed and duly executed officer's certificate in the form of Exhibit 7.1(c), together with a Covenant Compliance Worksheet.

"Consolidated Capitalization" means the sum of (a) all of the shareholders' equity or net worth of the Borrower and its Subsidiaries, as determined in accordance with GAAP plus (b) Consolidated Indebtedness.

"Consolidated EBITDA" means, for any period, an amount equal to (a) Consolidated Net Income (excluding any extraordinary gains and extraordinary losses) for such period plus (b) an amount which in the determination of Consolidated Net Income for such period was deducted for (i) Consolidated Interest Expense, (ii) income tax expense, (iii) depreciation expense and (iv) amortization expense plus (c) non-cash items reducing Consolidated Net Income for such period less (d) non-cash items increasing Consolidated Net Income for such period.

"Consolidated Indebtedness" means, as of any date of determination, with respect to the Borrower and its Subsidiaries on a consolidated basis, an amount equal to all Indebtedness of the Borrower and its Subsidiaries as of such date.

"Consolidated Interest Expense" means, for any period, with respect to the Borrower and its Subsidiaries on a consolidated basis, an amount equal to total interest expense of the Borrower and its

4

Subsidiaries for such period (including, without limitation, all such interest expense accrued or capitalized during such period, whether or not actually paid during such period), as determined in accordance with GAAP.

"Consolidated Net Income" means the consolidated net income of the Borrower and its Subsidiaries, as determined in accordance with GAAP.

"Contingent Obligation" means, with respect to any Person, any direct or indirect liability of such Person with respect to any Indebtedness, liability or other obligation (the "primary obligation") of another Person (the "primary obligor"), whether or not contingent,
(a) to purchase, repurchase or otherwise acquire such primary obligation or any property constituting direct or indirect security therefor, (b) to advance or provide funds (i) for the payment or discharge of any such primary obligation or (ii) to maintain working capital or equity capital of the primary obligor or otherwise to maintain the net worth or solvency or any balance sheet item, level of income or financial condition of the primary obligor, (c) to purchase property, securities or services primarily for the purpose of assuring the owner of any such primary obligation of the ability of the primary obligor in respect thereof to make payment of such primary obligation or (d) otherwise to assure or hold harmless the owner of any such primary obligation against loss or failure or inability to perform in respect thereof; provided, however, that, with respect to the Borrower and its Subsidiaries, the term Contingent Obligation shall not include endorsements for collection or deposit in the ordinary course of business. The amount of any Contingent Obligation of any Person shall be deemed to be an amount equal to the maximum amount of such Person's liability with respect to the stated or determinable amount of the primary obligation for which such Contingent Obligation is incurred or, if not stated or determinable, the maximum reasonably anticipated liability in respect thereof (assuming such Person is required to perform thereunder).

"Covenant Compliance Worksheet" shall mean a fully completed worksheet in the form of Attachment A to Exhibit 7.1(c).

"Credit Agreement" has the meaning set forth in the Preamble hereof.

"Credit Documents" means this Credit Agreement, the Revolving Notes, any Notice of Borrowing, any Notice of Continuation/Conversion, and any other document, agreement or instrument entered into or executed in connection with the foregoing.

"Credit Extension" means each of the following: (a) a Borrowing and (b) an L/C Credit Extension.

"Debt Rating" means the long term unsecured senior non-credit enhanced debt rating of the Borrower by S&P and Moody's.

5

"Debtor Relief Laws" means the Bankruptcy Code, and all other liquidation, conservatorship, bankruptcy, assignment for the benefit of

creditors, moratorium, rearrangement, receivership, insolvency, reorganization, or similar debtor relief Laws of the United States or other applicable jurisdictions from time to time in effect and affecting the rights of creditors generally.

"Default" means any event, act or condition which with notice or lapse of time, or both, would constitute an Event of Default.

"Default Rate" means an interest rate equal to two percent (2%) plus the rate that otherwise would be applicable (or if no rate is applicable, the Base Rate plus two percent (2%) per annum).

"Defaulting Lender" means, at any time, any Lender that, (a) has failed to make a Revolving Loan or purchase or fund a Participation Interest (but only for so long as such Revolving Loan is not made or such Participation Interest is not purchased or funded), (b) has failed to pay to the Administrative Agent or any Lender an amount owed by such Lender pursuant to the terms of this Credit Agreement (but only for so long as such amount has not been repaid) or (c) has been deemed insolvent or has become subject to a bankruptcy or insolvency proceeding or to a receiver, trustee or similar official.

"Dollars" and "$" means dollars in lawful currency of the United States of America.

"Eligible Assignee" means (a) a Lender, (b) an Affiliate of a Lender, (c) an Approved Fund and (d) any other Person approved by the Administrative Agent, the L/C Issuer and the Borrower (such approval not to be unreasonably withheld or delayed); provided that (i) the Borrower's consent is not required during the existence and continuation of a Default or an Event of Default, (ii) approval by the Borrower shall be deemed given if no objection is received by the assigning Lender and the Administrative Agent from the Borrower within five Business Days after notice of such proposed assignment has been delivered to the Borrower and (iii) neither the Borrower nor any Subsidiary or Affiliate of the Borrower shall qualify as an Eligible Assignee.

"Environmental Claims" means any and all administrative, regulatory or judicial actions, suits, demands, demand letters, claims, liens, accusations, allegations, notices of noncompliance or violation, investigations (other than internal reports prepared by any Person in the ordinary course of its business and not in response to any third party action or request of any kind) or proceedings relating in any way to any actual or alleged violation of or liability under any Environmental Law or relating to any permit issued, or any approval given, under any such Environmental Law (collectively, "Claims"), including, without limitation, (a) any and all Claims by Governmental Authorities for enforcement, cleanup, removal, response, remedial or other actions or damages pursuant to any applicable Environmental Law and (b) any and all Claims by any third party seeking damages, contribution, indemnification, cost recovery, compensation or injunctive relief resulting from Hazardous Substances or arising from alleged injury or threat of injury to human health or the environment.

6

"Environmental Laws" shall mean any and all federal, state and local laws, statutes, ordinances, rules, regulations, permits, licenses, approvals, rules of common law and orders of courts or Governmental Authorities, relating to the protection of human health or occupational safety or the environment, now or hereafter in effect and in each case as amended from time to time, including, without limitation, requirements pertaining to the manufacture, processing, distribution, use, treatment, storage, disposal, transportation, handling, reporting, licensing, permitting, investigation or remediation of Hazardous Substances.

"ERISA" means the Employee Retirement Income Security Act of 1974, as amended from time to time, and any successor statute, and all rules and regulations from time to time promulgated thereunder.

"ERISA Affiliate" means any Person (including any trade or business, whether or not incorporated) that would be deemed to be under "common control" with, or a member of the same "controlled group" as, the Borrower or any of its Subsidiaries, within the meaning of Sections
414(b), (c), (m) or (o) of the Code or Section 4001 of ERISA.

"ERISA Event" means: (a) a Reportable Event with respect to a Plan or a Multiemployer Plan, (b) a complete or partial withdrawal by the Borrower, any of its Subsidiaries or any ERISA Affiliate from a Multiemployer Plan, or the receipt by the Borrower, any of its Subsidiaries or any ERISA Affiliate of notice from a Multiemployer Plan that it is in reorganization or insolvency pursuant to Section 4241 or 4245 of ERISA or that it intends to terminate or has terminated under
Section 4041A of ERISA, (c) the distribution by the Borrower, any of its Subsidiaries or any ERISA Affiliate under Section 4041 or 4041A of ERISA of a notice of intent to terminate any Plan or the taking of any action to terminate any Plan, (d) the commencement of proceedings by the PBGC under Section 4042 of ERISA for the termination of, or the appointment of a trustee to administer, any Plan, or the receipt by the Borrower, any of its Subsidiaries or any ERISA Affiliate of a notice from any Multiemployer Plan that such action has been taken by the PBGC with respect to such Multiemployer Plan, (e) the institution of a proceeding by any fiduciary of any Multiemployer Plan against the Borrower, any of its Subsidiaries or any ERISA Affiliate to enforce
Section 515 of ERISA, which is not dismissed within thirty (30) days,
(f) the imposition upon the Borrower, any of its Subsidiaries or any ERISA Affiliate of any liability under Title IV of ERISA, other than for PBGC premiums due but not delinquent under Section 4007 of ERISA, or the imposition or threatened imposition of any Lien upon any assets of the Borrower, any of its Subsidiaries or any ERISA Affiliate as a result of any alleged failure to comply with the Code or ERISA in respect of any Plan, (g) the engaging in or otherwise becoming liable for a nonexempt Prohibited Transaction by the Borrower, any of its Subsidiaries or any ERISA Affiliate, (h) a violation of the applicable requirements of Section 404 or 405 of ERISA or the exclusive benefit rule under Section 401(a) of the Code by any fiduciary of any Plan for which the Borrower, any of its Subsidiaries or any ERISA Affiliate may be directly or indirectly liable, (i) the adoption of an amendment to any Plan that, pursuant to Section 401(a)(29) of the Code or Section 307 of ERISA, would result in the loss of tax-exempt status of the trust of which such Plan is a part if the Borrower, any of its Subsidiaries or any ERISA Affiliate fails to timely provide security to such Plan in accordance with the provisions of such sections or (j) the withdrawal of the Borrower, any of its Subsidiaries or any ERISA Affiliate from a Multiple Employer Plan during a play year in which it was a substantial employer (as such term is defined in Section 4001(a)(2) of ERISA), or the termination of a Multiple Employer Plan.

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"Eurodollar Loan" means a Revolving Loan bearing interest based at a rate determined by reference to the Adjusted Eurodollar Rate.

"Eurodollar Rate" means for any Interest Period with respect to any Eurodollar Loan:

(a) the rate per annum equal to the rate determined by the Administrative Agent to be the offered rate that appears on the page of the Telerate screen (or any successor thereto) that displays an average British Bankers Association Interest Settlement Rate for deposits in Dollars (for delivery on the first day of such Interest Period) with a term equivalent to such Interest Period, determined as of approximately 11:00 a.m. (London time) two Business Days prior to the first day of such Interest Period, or

(b) if the rate referenced in the preceding clause (i) does not appear on such page or service or such page or service shall not be available, the rate per annum equal to the rate determined by the Administrative Agent to be the offered rate on such other page or other service that displays an average British Bankers Association Interest Settlement Rate for deposits in Dollars (for delivery on the first day of such Interest Period) with a term equivalent to such Interest Period, determined as of approximately 11:00 a.m. (London time) two Business Days prior to the first day of such Interest Period, or

(c) if the rates referenced in the preceding clauses (i) and (ii) are not available, the rate per annum reasonably determined by the Administrative Agent as the rate of interest at which deposits in Dollars for delivery on the first day of such Interest Period in same day funds in the approximate amount of the Eurodollar Loan being made, continued or converted by Bank of America and with a term equivalent to such Interest Period would be offered by Bank of America's London Branch to major banks in the London interbank eurodollar market at their request at approximately 4:00 p.m. (London time) two Business Days prior to the first day of such Interest Period.

"Event of Default" has the meaning set forth in Section 9.1.

"Exchange Act" means the Securities Exchange Act of 1934, and the rules and regulations promulgated thereunder, as amended, modified, succeeded or replaced from time to time.

8

"Existing Credit Agreement" means that certain Credit Agreement, dated as of March 11, 1998, among the Borrower, the lenders party thereto, and The Chase Manhattan Bank, as Administrative Agent, as previously amended, modified or supplemented prior to the Closing Date.

"Existing Letters of Credit" means the letters of credit set forth on Schedule 1.1(c).

"Federal Funds Rate" means, for any day, the rate per annum equal to the weighted average (rounded upward, if necessary, to a whole multiple of 1/100 of 1%) of the rates on overnight Federal funds transactions with members of the Federal Reserve System arranged by Federal funds brokers on such day, as published by the Federal Reserve Bank on the Business Day next succeeding such day; provided that (a) if such day is not a Business Day, the Federal Funds Rate for such day shall be such rate on such transactions on the next preceding Business Day as so published on the next succeeding Business Day, and (b) if no such rate is so published on such next succeeding Business Day, the Federal Funds Rate for such day shall be the average rate (rounded upward, if necessary, to a whole multiple of 1/100 of 1%) charged to Bank of America on such day on such transactions as determined by the Administrative Agent.

"Fee Letter" means that certain letter agreement, dated as of November 22, 2002, among the Borrower, Bank of America and the Arranger, as amended, modified, supplemented or restated from time to time.

"Financial Officer" means the chief financial officer, vice president-finance, principal accounting officer or treasurer of the Borrower.

"First Mortgage Bonds" means those first mortgage bonds issued pursuant to the FMB Indenture.

"FMB Indenture" means the Indenture of Mortgage and Deed of Trust, dated as of June 1, 1947, between the Borrower and The Bank of New York (formerly Irving Trust Company), as trustee thereunder, as supplemented and amended.

"Foreign Lender" has the meaning set forth in Section 3.13(f).

"Fund" means any Person (other than a natural person) that is (or will be) engaged in making, purchasing, holding or otherwise investing in commercial loans and similar extensions of credit in the ordinary course of its business.

"GAAP" means generally accepted accounting principles in the United States set forth in the opinions and pronouncements of the Accounting Principles Board and the American Institute of Certified Public Accountants and statements and pronouncements of the Financial Accounting Standards Board (or agencies with similar functions of comparable stature and authority within the U.S. accounting profession) or that are promulgated by any Governmental Authority having appropriate jurisdiction.

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"Government Acts" has the meaning set forth in Section 2.2(k).

"Governmental Authority" means any domestic or foreign nation or government, any state or other political subdivision thereof and any central bank thereof, any municipal, local, city or county government, and any entity exercising executive, legislative, judicial, regulatory or administrative functions of or pertaining to government (including, without limitation, any state dental board) and any corporation or other entity owned or controlled, through stock or capital ownership or otherwise, by any of the foregoing.

"Granting Lender" has the meaning specified in Section 11.3(g).

"Hazardous Substances" means any substances or materials (a) that are or become defined as hazardous wastes, hazardous substances, pollutants, contaminants or toxic substances under any Environmental Law, (b) that are defined by any Environmental Law as toxic, explosive, corrosive, ignitable, infectious, radioactive, mutagenic or otherwise hazardous, (c) the presence of which require investigation or response under any Environmental Law, (d) that constitute a nuisance, trespass or health or safety hazard to Persons or neighboring properties, (e) that consist of underground or aboveground storage tanks, whether empty, filled or partially filled with any substance, or (f) that contain, without limitation, asbestos, polychlorinated biphenyls, urea formaldehyde foam insulation, petroleum hydrocarbons, petroleum derived substances or wastes, crude oil, nuclear fuel, natural gas or synthetic gas.

"Hedging Agreements" means, collectively, interest rate protection agreements, equity index agreements, foreign currency exchange agreements, option agreements or other interest or exchange rate or commodity price hedging agreements.

"Indebtedness" means, with respect to any Person (without duplication), (a) all indebtedness and obligations of such Person for borrowed money or in respect of loans or advances of any kind, (b) all obligations of such Person evidenced by notes, bonds, debentures or similar instruments, (c) all reimbursement obligations of such Person with respect to surety bonds, letters of credit and bankers' acceptances (in each case, whether or not drawn or matured and in the stated amount thereof), (d) all obligations of such Person to pay the deferred purchase price of property or services, (e) all indebtedness created or arising under any conditional sale or other title retention agreement with respect to property acquired by such Person, (f) all obligations of such Person as lessee under leases that are or are required to be, in accordance with GAAP, recorded as capital leases, to the extent such obligations are required to be so recorded, (g) the net termination obligations of such Person under any Hedging Agreements, calculated as of any date as if such agreement or arrangement were terminated as of such date in accordance with the applicable rules under GAAP, (h) all Contingent Obligations of such Person, (i) all obligations and liabilities of such Person incurred in connection with any transaction or series of transactions providing for the financing of assets through one or more securitizations or in connection with, or pursuant to, any synthetic lease or similar off-balance sheet financing, (j) the aggregate amount of uncollected accounts receivable of such Person subject at the time of determination to a sale of receivables (or similar transaction) to the extent such transaction is effected with recourse to such Person (whether or not such transaction would be reflected on the balance sheet of such Person in accordance with GAAP), (k) all obligations, contingent or otherwise, under the Material Leases and (l) all indebtedness referred to in clauses (a) through (k) above secured by any Lien on any property or asset owned or held by such Person regardless of whether the indebtedness secured thereby shall have been assumed by such Person or is nonrecourse to the credit of such Person.

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"Indemnified Liabilities" has the meaning set forth in Section 11.5(b).

"Indemnitees" has the meaning set forth in Section 11.5(b).

"Insured Series First Mortgage Bonds" means First Mortgage Bonds in the aggregate principal amount of $111,000,000 pledged by the Borrower to secure guarantees of $111,000,000 principal amount of pollution control revenue bonds issued by the City of Farmington, New Mexico, for the benefit of the Borrower, which pollution control revenue bonds are also supported by a municipal bond insurance policy issued by AMBAC Indemnity Corporation.

"Interest Payment Date" means, (a) as to any Eurodollar Loan, the last day of each Interest Period applicable to such Loan and the Maturity Date; provided, however, that if any Interest Period for a Eurodollar Loan exceeds three months, the respective dates that fall every three months after the beginning of such Interest Period shall also be Interest Payment Dates and (b) as to any Base Rate Loan, the last Business Day of each fiscal quarter of the Borrower and the Maturity Date.

"Interest Period" means, as to each Eurodollar Loan, the period commencing on the date such Eurodollar Loan is disbursed or converted to or continued as a Eurodollar Loan and ending on the date one, two, three or six months thereafter, as selected by the Borrower in its Notice of Borrowing or Notice of Continuation/Conversion; provided that:

(a) any Interest Period that would otherwise end on a day that is not a Business Day shall be extended to the next succeeding Business Day unless such Business Day falls in another calendar month, in which case such Interest Period shall end on the next preceding Business Day;

(b) any Interest Period that begins on the last Business Day of a calendar month (or on a day for which there is no numerically corresponding day in the calendar month at the end of such Interest Period) shall end on the last Business Day of the calendar month at the end of such Interest Period; and

(c) no Interest Period shall extend beyond the Maturity Date.

"Laws" means, collectively, all international, foreign, federal, state and local statutes, treaties, rules, guidelines, regulations, ordinances, codes and administrative or judicial precedents or authorities, including the interpretation or administration thereof by any Governmental Authority charged with the enforcement, interpretation or administration thereof, and all applicable administrative orders, directed duties, requests, licenses, authorizations and permits of, and agreements with, any Governmental Authority, in each case whether or not having the force of law.

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"L/C Credit Extension" means, with respect to any Letter of Credit, the issuance thereof, the extension of the expiry date thereof, the renewal or increase of the amount thereof or any extension of credit resulting from a drawing thereunder that has not been reimbursed.

"L/C Fees" has the meaning set forth in Section 3.4(c).

"L/C Fronting Fee" has the meaning set forth in Section 2.2(i).

"L/C Issuer" means (a) solely with respect to the Existing Letters of Credit, J.P. Morgan Chase Bank in its capacity as issuer of such Existing Letters of Credit and (b) with respect to all other Letters of Credit, Bank of America in its capacity as issuer of such Letters of Credit hereunder, or any successor issuer of Letters of Credit hereunder.

"L/C Obligations" means, as of any date of determination, the aggregate undrawn amount of all outstanding Letters of Credit plus the aggregate of all unreimbursed drawings under any Letter of Credit.

"Lender" means any of the Persons identified as a "Lender" on the signature pages hereto, and any Eligible Assignee which may become a Lender by way of assignment in accordance with the terms hereof, together with their successors and permitted assigns.

"Lending Office" means, as to any Lender, the office or offices of such Lender described as such in such Lender's Administrative Questionnaire, or such other office or offices as a Lender may from time to time notify the Borrower and the Administrative Agent.

"Letter of Credit" means any letter of credit issued hereunder and shall include the Existing Letters of Credit.

"Letter of Credit Application" means an application and agreement for the issuance or amendment of a Letter of Credit in the form from time to time in use by the L/C Issuer.

"Letter of Credit Expiration Date" means the day that is ten days prior to the Maturity Date then in effect (or, if such day is not a Business Day, the next preceding Business Day).

"Letter of Credit Sublimit" means an amount equal to FIFTY MILLION DOLLARS ($50,000,000). The Letter of Credit Sublimit is part of, and not in addition to, the Revolving Committed Amount.

"Lien" means any mortgage, pledge, hypothecation, assignment, security interest, lien (statutory or otherwise), preference, priority, charge or other encumbrance of any nature, whether voluntary or involuntary, including, without limitation, the interest of any vendor or lessor under any conditional sale agreement, title retention agreement, capital lease or any other lease or arrangement having substantially the same effect as any of the foregoing.

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"Mandatory Borrowing" has the meaning set forth in Section 2.2(d).

"Margin Stock" has the meaning ascribed to such term in Regulation U.

"Material Adverse Change" means a material adverse change in the condition (financial or otherwise), operations, business, performance, properties or assets of the Borrower and its Subsidiaries, taken as a whole.

"Material Adverse Effect" means a material adverse effect upon
(a) the business, assets, liabilities (actual or contingent), operations, condition (financial or otherwise) or prospects of the Borrower and its Subsidiaries, taken as a whole, (b) the ability of the Borrower to perform its obligations under this Credit Agreement or any of the other Credit Documents or (c) the legality, validity or enforceability of this Credit Agreement or any of the other Credit Documents or the rights and remedies of the Administrative Agent and the Lenders hereunder and thereunder.

"Material Lease" means any lease to the Borrower of its leasehold interests in (i) Unit 1 or Unit 2, and related common facilities, of the Palo Verde Nuclear Generating Station or (ii) the electric transmission line, and related facilities, known as the Eastern Interconnection Project, including, without limitation, any lease set forth on Schedule 6.18 hereto.

"Maturity Date" means December 18, 2003.

"Moody's" means Moody's Investors Service, Inc. and its successors.

"Multiemployer Plan" means any "multiemployer plan" within the meaning of Section 4001(a)(3) of ERISA to which the Borrower, any of its Subsidiaries or any ERISA Affiliate makes, is making or is obligated to make contributions or has made or been obligated to make contributions.

"Multiple Employer Plan" means a Single Employer Plan to which the Borrower, any of its Subsidiaries or any ERISA Affiliate and at least one employer other than the Borrower, any of its Subsidiaries or any ERISA Affiliate are contributing sponsors.

"Nonrenewal Notice Date" has the meaning set forth in Section 2.2(b)(iii).

"Notice of Borrowing" means a request by the Borrower for a Revolving Loan in the form of Exhibit 2.1(b).

"Notice of Continuation/Conversion" means a request by the Borrower to continue an existing Eurodollar Loan to a new Interest Period or to convert a Eurodollar Loan to a Base Rate Loan or a Base Rate Loan to a Eurodollar Loan, in the form of Exhibit 2.3.

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"Other Taxes" has the meaning set forth in Section 3.13(b).

"PBGC" means the Pension Benefit Guaranty Corporation and any successor thereto.

"Participant" has the meaning set forth in Section 11.3(d).

"Participation Interest" means (a) the purchase by a Lender of a participation in Letters of Credit or L/C Obligations as provided in
Section 2.2 or (b) the purchase by a Lender of a participation in any Revolving Loan as provided in Section 3.8.

"Person" means any individual, partnership, joint venture, firm, corporation, limited liability company, association, trust or other enterprise (whether or not incorporated), or any Governmental Authority.

"Plan" means any "employee benefit plan" (within the meaning of Section 3(3) of ERISA) which is covered by ERISA and with respect to which the Borrower, any of its Subsidiaries or any ERISA Affiliate is (or, if such plan were terminated at such time, would under Section 4069 of ERISA be deemed to be) an "employer" within the meaning of
Section 3(5) of ERISA.

"Prime Rate" has the meaning set forth in the definition of Base Rate in this Section 1.1.

"Pro Rata Share" means, with respect to each Lender at any time, a fraction (expressed as a percentage, carried out to the ninth decimal place), the numerator of which is the amount of the Commitment of such Lender at such time and the denominator of which is the amount of the Revolving Committed Amount at such time; provided that if the Commitment of each Lender to make Revolving Loans and the obligation of the L/C Issuer to make L/C Credit Extensions have been terminated pursuant to Section 9.2 or otherwise, then the Pro Rata Share of each Lender shall be determined based on such Lender's percentage ownership of the sum of the aggregate amount of outstanding Revolving Loans plus the aggregate amount of outstanding L/C Obligations. The initial Pro Rata Share of each Lender is set forth opposite the name of such Lender on Schedule 1.1(a) or in the Assignment and Assumption pursuant to which such Lender becomes a party hereto, as applicable.

"Prohibited Transaction" means any transaction described in
(a) Section 406 of ERISA that is not exempt by reason of Section 408 of ERISA or by reason of a Department of Labor prohibited transaction individual or class exemption or (b) Section 4975(c) of the Code that is not exempt by reason of Section 4975(c)(2) or 4975(d) of the Code.

"Property" means any right, title or interest in or to any property or asset of any kind whatsoever, whether real, personal or mixed and whether tangible or intangible.

"Register" has the meaning set forth in Section 11.3(c).

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"Regulations T, U and X" means Regulations T, U and X, respectively, of the Federal Reserve Board, and any successor regulations.

"Reportable Event" means (a) any "reportable event" within the meaning of Section 4043(c) of ERISA for which the notice under Section 4043(a) of ERISA has not been waived by the PBGC (including any failure to meet the minimum funding standard of, or timely make any required installment under, Section 412 of the Code or Section 302 of ERISA, regardless of the issuance of any waivers in accordance with Section 412(d) of the Code), (b) any such "reportable event" subject to advance notice to the PBGC under Section 4043(b)(3) of ERISA, (c) any application for a funding waiver or an extension of any amortization period pursuant to Section 412 of the Code, and (d) a cessation of operations described in Section 4062(e) of ERISA.

"Required Lenders" means Lenders whose aggregate Credit Exposure (as hereinafter defined) constitutes more than 50% of the Credit Exposure of all Lenders at such time; provided, however, that if any Lender shall be a Defaulting Lender at such time then there shall be excluded from the determination of Required Lenders the aggregate principal amount of Credit Exposure of such Lender at such time. For purposes of the preceding sentence, the term "Credit Exposure" as applied to each Lender shall mean (a) at any time prior to the termination of the Commitments, the Pro Rata Share of such Lender of the Revolving Committed Amount multiplied by the Revolving Committed Amount and (b) at any time after the termination of the Commitments, the sum of (i) the principal balance of the outstanding Revolving Loans of such Lender plus (ii) such Lender's Participation Interests in the face amount of the outstanding Letters of Credit.

"Requirement of Law" means, with respect to any Person, the organizational documents of such Person and any Law applicable to or binding upon such Person or any of its property or to which such Person or any of its property is subject or otherwise pertaining to any or all of the transactions contemplated by this Credit Agreement and the other Credit Documents.

"Responsible Officer" means the president, the chief executive officer, the co-chief executive officer, the chief financial officer, any executive officer, vice president-finance, principal accounting officer or treasurer of the Borrower, and any other officer or similar official thereof responsible for the administration of the obligations of the Borrower in respect of this Credit Agreement and the other Credit Documents.

"Revolving Committed Amount" means ONE HUNDRED NINETY-FIVE MILLION DOLLARS ($195,000,000) or such lesser amount, as it may be reduced from time to time in accordance with Section 2.1(d).

"Revolving Loans" or "Loans" has the meaning set forth in
Section 2.1(a).

15

"Revolving Notes" or "Notes" means the promissory notes of the Borrower in favor of each of the Lenders evidencing the Revolving Loans provided pursuant to Section 2.1, individually or collectively, as appropriate, as such promissory notes may be amended, modified, supplemented, extended, renewed or replaced from time to time and as evidenced in the form of Exhibit 2.1(e).

"S&P" means Standard & Poor's Rating Service, a division of The McGraw-Hill Companies, Inc. and its successors.

"Securities Act" means the Securities Act of 1933, as amended, and the rules and regulations promulgated thereunder.

"Single Employer Plan" means any Plan which is covered by Title IV of ERISA, but which is not a Multiemployer Plan or Multiple Employer Plan.

"Solvent" means, with respect to any Person as of a particular date, that on such date (a) such Person is able to pay its debts and other liabilities, Contingent Obligations and other commitments as they mature in the normal course of business, (b) such Person does not intend to, and does not believe that it will, incur debts or liabilities beyond such Person's ability to pay as such debts and liabilities mature in their ordinary course, (c) such Person is not engaged in a business or a transaction, and is not about to engage in a business or a transaction, for which such Person's assets would constitute unreasonably small capital after giving due consideration to the prevailing practice in the industry in which such Person is engaged or is to engage, (d) the fair value of the assets of such Person is greater than the total amount of liabilities, including, without limitation, Contingent Obligations, of such Person and (e) the present fair saleable value of the assets of such Person is not less than the amount that will be required to pay the probable liability of such Person on its debts as they become absolute and matured.

"SPC" has the meaning set forth in Section 11.3(g).

"Subsidiary" means, as to any Person, (a) any corporation more than 50% of whose stock of any class or classes having by the terms thereof ordinary voting power to elect a majority of the directors of such corporation (irrespective of whether or not at the time, any class or classes of such corporation shall have or might have voting power by reason of the happening of any contingency) is at the time owned by such Person directly or indirectly through Subsidiaries, and (b) any partnership, association, joint venture or other entity in which such person directly or indirectly through Subsidiaries has more than a 50% equity interest at any time. Any reference to Subsidiary herein, unless otherwise identified, shall mean a Subsidiary, direct or indirect, of the Borrower. Any reference to a Subsidiary of the Borrower herein shall not include any Subsidiary that is inactive, has minimal or no assets and does not generate revenues.

"Taxes" has the meaning set forth in Section 3.13(a).

"3838 Securization" means the electric and gas accounts receivable securitization program which is the subject of New Mexico Public Regulation Commission in Case 3838.

"Total Assets" means all assets of the Borrower as shown on its most recent quarterly consolidated balance sheet, as determined in accordance with GAAP.

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"Type" means, with respect to a Revolving Loan, its character as a Base Rate Loan or a Eurodollar Loan.

"Unused Revolving Commitment" means, for any date of determination, the amount by which (a) the aggregate Revolving Committed Amount on such date exceeds (b) the sum of the aggregate principal amount of outstanding Revolving Loans plus the aggregate principal amount of outstanding L/C Obligations on such date.

"Utilization Fees" has the meaning set forth in Section 3.4(b).

"Voting Stock" means the Capital Stock of a Person that is then outstanding and normally entitled to vote in the election of directors and other securities of such Person convertible into or exercisable for such Capital Stock (whether or not such securities are then currently convertible or exercisable).

1.2 Computation of Time Periods and Other Definitional Provisions.

For purposes of computation of periods of time hereunder, the word "from" means "from and including" and the words "to" and "until" each mean "to but excluding." References in this Credit Agreement to "Articles", "Sections", "Schedules" or "Exhibits" shall be to Articles, Sections, Schedules or Exhibits of or to this Credit Agreement unless otherwise specifically provided.

1.3 Accounting Terms/Calculation of Financial Covenants.

Except as otherwise expressly provided herein, all accounting terms used herein or incorporated herein by reference shall be interpreted, and all financial statements and certificates and reports as to financial matters required to be delivered to the Administrative Agent or the Lenders hereunder shall be prepared, in accordance with GAAP applied on a consistent basis. Notwithstanding anything to the contrary in this Credit Agreement, for purposes of calculation of the financial covenants set forth in Section 7.2, all accounting determinations and computations thereunder shall be made in accordance with GAAP as in effect as of the date of this Credit Agreement applied on a basis consistent with the application used in preparing the most recent financial statements of the Borrower referred to in Section 4.1(d). In the event that any changes in GAAP after such date are required to be applied to the Borrower and would affect the computation of the financial covenants contained in Section 7.2, such changes shall be followed only from and after the date this Credit Agreement shall have been amended to take into account any such changes.

1.4 Time.

All references to time herein shall be references to Central Standard Time or Central Daylight time, as the case may be, unless specified otherwise.

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1.5 Rounding of Financial Covenants.

Any financial ratios required to be maintained by the Borrower pursuant to this Credit Agreement shall be calculated by dividing the appropriate component by the other component, carrying the result to one place more than the number of places by which such ratio is expressed herein and rounding the result up or down to the nearest number (with a rounding-up if there is no nearest number).

1.6 References to Agreements and Requirement of Laws.

Unless otherwise expressly provided herein: (a) references to organization documents, agreements (including the Credit Documents) and other contractual instruments shall be deemed to include all subsequent amendments, restatements, extensions, supplements and other modifications thereto, but only to the extent that such amendments, restatements, extensions, supplements and other modifications are not prohibited by any Credit Document and (b) references to any Requirement of Law shall include all statutory and regulatory provisions consolidating, amending, replacing, supplementing or interpreting such Requirement of Law.

SECTION 2

CREDIT FACILITY

2.1 Revolving Loans.

(a) Revolving Loan Commitment. Subject to the terms and conditions set forth herein, each Lender severally agrees to make revolving loans (each a "Revolving Loan" or "Loan" and collectively the "Revolving Loans" or "Loans") in Dollars to the Borrower, at any time and from time to time, during the period from and including the Closing Date to but not including the Maturity Date (or such earlier date if the Commitments have been terminated as provided herein); provided, however, that after giving effect to any Borrowing (i) the sum of the aggregate principal amount of outstanding Revolving Loans plus the aggregate principal amount of outstanding L/C Obligations shall not exceed the Revolving Committed Amount and (ii) with respect to each individual Lender, the sum of the aggregate principal amount of outstanding Revolving Loans plus the aggregate principal amount of outstanding L/C Obligations of such Lender shall not exceed such Lender's Pro Rata Share of the Revolving Committed Amount. Subject to the terms of this Credit Agreement (including Section 3.3), the Borrower may borrow, repay and reborrow Revolving Loans.

(b) Method of Borrowing for Revolving Loans. By no later than 11:00 a.m. (i) on the date of the requested Borrowing of Revolving Loans that will be Base Rate Loans and (ii) three Business Days prior to the date of the requested Borrowing of Revolving Loans that will be Eurodollar Loans, the Borrower shall telephone the Administrative Agent as well as submit a written Notice of Borrowing in the form of Exhibit

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2.1(b) to the Administrative Agent setting forth (A) the amount requested, (B) the date of the requested Borrowing, (C) the Type of Revolving Loan, (D) with respect to Revolving Loans that will be Eurodollar Loans, the Interest Period applicable thereto, and (E) certification that the Borrower has complied in all respects with
Section 5. If the Borrower shall fail to specify (1) an Interest Period in the case of a Eurodollar Loan, then such Eurodollar Loan shall be deemed to have an Interest Period of one month or (2) the Type of Revolving Loan requested, then such Revolving Loan shall be deemed to be a Base Rate Loan. All Revolving Loans made on the Closing Date shall be Base Rate Loans. Thereafter, all or any portion of the Revolving Loans may be converted into Eurodollar Loans in accordance with the terms of Section 2.3.

(c) Funding of Revolving Loans. Upon receipt of a Notice of Borrowing, the Administrative Agent shall promptly inform the Lenders as to the terms thereof. Each such Lender shall make its Pro Rata Share of the requested Revolving Loans available to the Administrative Agent in immediately available funds at the Administrative Agent's Office not later than 1:00 p.m. on the Business Day specified in the applicable Notice of Borrowing. Upon satisfaction of the conditions set forth in
Section 5, the amount of the requested Revolving Loans will then be made available to the Borrower by the Administrative Agent either by
(i) crediting the account of the Borrower on the books of the Administrative Agent with the amount of such funds or (ii) wire transfer of such funds, in each case in accordance with instructions provided to (and reasonably acceptable to) the Administrative Agent by the Borrower.

(d) Reductions of Revolving Committed Amount. Upon at least three Business Days' notice, the Borrower shall have the right to permanently terminate or reduce the aggregate unused amount of the Revolving Committed Amount at any time or from time to time; provided that (i) each partial reduction shall be in an aggregate amount at least equal to $5,000,000 and in integral multiples of $1,000,000 above such amount and (ii) no reduction shall be made which would reduce the Revolving Committed Amount to an amount less than the sum of the aggregate principal amount of outstanding Revolving Loans plus the aggregate principal amount of outstanding L/C Obligations. Any reduction in (or termination of) the Revolving Committed Amount shall be permanent and may not be reinstated.

(e) Revolving Notes. The Revolving Loans made by each Lender shall be evidenced by a duly executed promissory note of the Borrower to such Lender in substantially the form of Exhibit 2.1(e).

2.2 Letter of Credit Subfacility.

(a) The Letter of Credit Commitment.

(i) Subject to the terms and conditions set forth herein and other terms and conditions that the L/C Issuer may reasonably require, (A) the L/C Issuer agrees, in reliance upon the agreements of the other Lenders set forth in this
Section 2.2, from time to time on any Business Day during the period from the Closing Date until the Letter of Credit Expiration Date, to issue standby Letters of Credit in Dollars

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for the account of the Borrower and to amend Letters of Credit previously issued by it, in each case in accordance with subsection (b) below and (B) the Lenders severally agree to participate in Letters of Credit issued for the account of the Borrower; provided, however, that after giving effect to the issuance of any Letter of Credit (1) the sum of the aggregate principal amount of outstanding Revolving Loans plus the aggregate principal amount of outstanding L/C Obligations shall not exceed the Revolving Committed Amount, (2) with respect to each individual Lender, the sum of the aggregate principal amount of outstanding Revolving Loans of such Lender plus the aggregate principal amount of outstanding L/C Obligations of such Lender shall not exceed such Lender's Pro Rata Share of the Revolving Committed Amount and (3) the aggregate amount of L/C Obligations shall not at any time exceed the Letter of Credit Sublimit. Within the foregoing limits, and subject to the terms and conditions hereof, the Borrower may, during the foregoing period, obtain Letters of Credit to replace Letters of Credit that have expired or that have been drawn upon and reimbursed.

(ii) The L/C Issuer shall not issue or amend any Letter of Credit if:

(A) any order, judgment or decree of any Governmental Authority or arbitrator shall by its terms purport to enjoin or restrain the L/C Issuer from issuing such Letter of Credit, or any Requirement of Law applicable to the L/C Issuer or any request or directive (whether or not having the force of law) from any Governmental Authority with jurisdiction over the L/C Issuer shall prohibit, or request that the L/C Issuer refrain from, the issuance of letters of credit generally or such Letter of Credit in particular or shall impose upon the L/C Issuer with respect to such Letter of Credit any restriction, reserve or capital requirement (for which the L/C Issuer is not otherwise compensated hereunder) not in effect on the Closing Date, or shall impose upon the L/C Issuer any unreimbursed loss, cost or expense which was not applicable on the Closing Date and which the L/C Issuer in good faith deems material to it;

(B) the expiry date of such requested Letter of Credit would occur more than twelve months after the date of issuance, unless the Required Lenders have approved such expiry date;

(C) the expiry date of such requested Letter of Credit would occur after the Letter of Credit Expiration Date, unless all the Lenders have approved such expiry date;

(D) the issuance of such Letter of Credit would violate one or more policies of the L/C Issuer; or

(E) such Letter of Credit is in an initial amount less than $100,000 (unless otherwise agreed to by the L/C Issuer), is to be used for a purpose other than as permitted by Section 7.11, or is denominated in a currency other than Dollars.

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(iii) The L/C Issuer shall be under no obligation to amend any Letter of Credit if (A) the L/C Issuer would have no obligation at such time to issue such Letter of Credit in its amended form under the terms hereof or (B) the beneficiary of such Letter of Credit does not accept the proposed amendment to such Letter of Credit.

(b) Procedures for Issuance and Amendment of Letters of Credit.

(i) Each Letter of Credit shall be issued or amended, as the case may be, upon the request of the Borrower delivered to the L/C Issuer (with a copy to the Administrative Agent) in the form of a Letter of Credit Application, appropriately completed and signed by a Responsible Officer of the Borrower. The Letter of Credit Application must be received by the L/C Issuer and the Administrative Agent not later than 11:00 a.m. at least two Business Days (or such later date and time as the L/C Issuer may agree in a particular instance in its sole discretion) prior to the proposed issuance date or date of amendment, as applicable. In the case of a request for an initial issuance of a Letter of Credit, such Letter of Credit Application shall specify in form and detail satisfactory to the L/C Issuer: (A) the proposed issuance date of the requested Letter of Credit (which shall be a Business Day), (B) the amount thereof, (C) the expiry date thereof, (D) the name and address of the beneficiary thereof, (E) the documents to be presented by such beneficiary in case of any drawing thereunder, (F) the full text of any certificate to be presented by such beneficiary in case of any drawing thereunder and (G) such other matters as the L/C Issuer may require. In the case of a request for an amendment of any outstanding Letter of Credit, such Letter of Credit Application shall specify in form and detail satisfactory to the L/C Issuer (1) the Letter of Credit to be amended, (2) the proposed date of amendment thereof (which shall be a Business Day), (3) the nature of the proposed amendment and (4) such other matters as the L/C Issuer may require.

(ii) Promptly after receipt of any Letter of Credit Application, the L/C Issuer will confirm with the Administrative Agent (by telephone or in writing) that the Administrative Agent has received a copy of such Letter of Credit Application from the Borrower and, if not, the L/C Issuer will provide the Administrative Agent with a copy thereof. Upon receipt by the L/C Issuer of confirmation from the Administrative Agent that the requested issuance or amendment is permitted in accordance with the terms hereof, then, subject to the terms and conditions hereof, the L/C Issuer shall, on the requested date, issue a Letter of Credit for the account of the Borrower or enter into the applicable amendment, as the case may be, in each case in accordance with the L/C Issuer's usual and customary business practices.

(iii) If the Borrower so requests in any applicable Letter of Credit Application, the L/C Issuer may, in its sole and absolute discretion, agree to issue a Letter of Credit that has automatic renewal provisions (each, an "Auto-Renewal Letter of Credit"); provided that any such Auto-Renewal Letter of Credit must permit the L/C Issuer to prevent any such renewal at least once in each twelve-month period (commencing

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with the date of issuance of such Letter of Credit) by giving prior notice to the beneficiary thereof not later than a day (the "Nonrenewal Notice Date") in each such twelve-month period to be agreed upon at the time such Letter of Credit is issued. Unless otherwise directed by the L/C Issuer, the Borrower shall not be required to make a specific request to the L/C Issuer for any such renewal. Once an Auto-Renewal Letter of Credit has been issued, the Lenders shall be deemed to have authorized (but may not require) the L/C Issuer to permit the renewal of such Letter of Credit at any time to an expiry date not later than the Letter of Credit Expiration Date; provided, however, that the L/C Issuer shall not permit any such renewal if (A) the L/C Issuer has determined that it would have no obligation at such time to issue such Letter of Credit in its renewed form under the terms hereof (by reason of the provisions of Section 2.2(a)(ii) or otherwise), or (B) it has received notice (which may be by telephone or in writing) on or before the day that is two Business Days before the Nonrenewal Notice Date (1) from the Administrative Agent that the Required Lenders have elected not to permit such renewal or (2) from the Administrative Agent, any Lender or the Borrower that one or more of the applicable conditions specified in Section 5 is not then satisfied.

(iv) Promptly after its delivery of any Letter of Credit or any amendment to a Letter of Credit to an advising bank with respect thereto or to the beneficiary thereof, the L/C Issuer will also deliver to the Borrower and the Administrative Agent a true and complete copy of such Letter of Credit or amendment.

(c) Participations.

(i) On the Closing Date, each Lender shall be deemed to have purchased without recourse a risk participation from the L/C Issuer in each Existing Letter of Credit and the obligations arising thereunder and any collateral relating thereto, in each case in an amount equal to its Pro Rata Share of the obligations under such Existing Letter of Credit, and shall absolutely, unconditionally and irrevocably assume, as primary obligor and not as surety, and be obligated to pay to the L/C Issuer therefor and discharge when due, its Pro Rata Share of the obligations arising under such Existing Letter of Credit.

(ii) Each Lender, upon issuance of a Letter of Credit, shall be deemed to have purchased without recourse a risk participation from the L/C Issuer in such Letter of Credit and the obligations arising thereunder and any collateral relating thereto, in each case in an amount equal to its Pro Rata Share of the obligations under such Letter of Credit, and shall absolutely, unconditionally and irrevocably assume, as primary obligor and not as surety, and be obligated to pay to the L/C Issuer therefor and discharge when due, its Pro Rata Share of the obligations arising under such Letter of Credit.

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(d) Reimbursement.

(i) In the event of any drawing under any Letter of Credit, the L/C Issuer will promptly notify the Borrower. The Borrower shall reimburse the L/C Issuer on the day of drawing under any Letter of Credit either with the proceeds of a Revolving Loan obtained hereunder or otherwise in immediately available funds. If the Borrower shall fail to reimburse the L/C Issuer as provided hereinabove, the unreimbursed amount of such drawing shall bear interest at a per annum rate equal to the Base Rate plus two percent (2%).

(ii) Subsequent to a drawing under any Letter of Credit, unless the Borrower shall immediately notify the L/C Issuer of its intent to otherwise reimburse the L/C Issuer, the Borrower shall be deemed to have requested a Base Rate Loan in the amount of the drawing as described herein, the proceeds of which will be used to satisfy the reimbursement obligations. On any day on which the Borrower shall be deemed to have requested a Revolving Loan borrowing to reimburse a drawing under a Letter of Credit, the Administrative Agent shall give notice to the Lenders that a Revolving Loan has been deemed requested in connection with a drawing under a Letter of Credit, in which case a Revolving Loan borrowing comprised solely of Base Rate Loans (each such borrowing, a "Mandatory Borrowing") shall be immediately made from all Lenders (without giving effect to any termination of the Commitments pursuant to Section 9.2 or otherwise) pro rata based on each Lender's respective Pro Rata Share and the proceeds thereof shall be paid directly to the L/C Issuer for application to the respective L/C Obligations. Each Lender hereby irrevocably agrees to make such Revolving Loans immediately upon any such request or deemed request on account of each such Mandatory Borrowing in the amount and in the manner specified in the preceding sentence and on the same such date notwithstanding (A) the amount of Mandatory Borrowing may not comply with the minimum amount for borrowings of Revolving Loans otherwise required hereunder, (B) the failure of any conditions specified in Section 5.2 to have been satisfied, (C) the existence of a Default or an Event of Default, (D) the failure of any such request or deemed request for Revolving Loans to be made by the time otherwise required hereunder, (E) the date of such Mandatory Borrowing, or (F) any reduction in the Revolving Committed Amount or any termination of the Commitments.

(iii) In the event that any Mandatory Borrowing cannot for any reason be made on the date otherwise required above (including, without limitation, as a result of the commencement of a proceeding under the Bankruptcy Code with respect to the Borrower), then each such Lender hereby agrees that it shall forthwith fund (as of the date the Mandatory Borrowing would otherwise have occurred, but adjusted for any payments received from the Borrower on or after such date and prior to such purchase) its Pro Rata Share in the outstanding L/C Obligations; provided, that in the event any Lender shall

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fail to fund its Pro Rata Share on the day the Mandatory Borrowing would otherwise have occurred, then the amount of such Lender's unfunded participation interest therein shall bear interest payable to the L/C Issuer upon demand, at the rate equal to, if paid within two Business Days of such date, the Federal Funds Rate, and thereafter at a rate equal to the Base Rate. Simultaneously with the making of each such payment by a Lender to the L/C Issuer, such Lender shall, automatically and without any further action on the part of the L/C Issuer or such Lender, acquire a participation in an amount equal to such payment (excluding the portion of such payment constituting interest owing to the L/C Issuer) in the related unreimbursed drawing portion of the L/C Obligation and in the interest thereon and shall have a claim against the Borrower with respect thereto. Any payment by the Lenders pursuant to this clause (iii) shall not relieve or otherwise impair the obligations of the Borrower to reimburse the L/C Issuer under a Letter of Credit.

(e) Obligations Absolute. The obligation of the Borrower to reimburse the L/C Issuer for each drawing under each Letter of Credit shall be absolute, unconditional and irrevocable, and shall be paid strictly in accordance with the terms of this Credit Agreement under all circumstances, including the following:

(i) any lack of validity or enforceability of such Letter of Credit, this Credit Agreement, or any other agreement or instrument relating thereto;

(ii) the existence of any claim, counterclaim, set-off, defense or other right that the Borrower may have at any time against any beneficiary or any transferee of such Letter of Credit (or any Person for whom any such beneficiary or any such transferee may be acting), the L/C Issuer or any other Person, whether in connection with this Credit Agreement, the transactions contemplated hereby or by such Letter of Credit or any agreement or instrument relating thereto, or any unrelated transaction;

(iii) any draft, demand, certificate or other document presented under such Letter of Credit proving to be forged, fraudulent, invalid or insufficient in any respect or any statement therein being untrue or inaccurate in any respect; or any loss or delay in the transmission or otherwise of any document required in order to make a drawing under such Letter of Credit;

(iv) any payment by the L/C Issuer under such Letter of Credit against presentation of a draft or certificate that does not strictly comply with the terms of such Letter of Credit; or any payment made by the L/C Issuer under such Letter of Credit to any Person purporting to be a trustee in bankruptcy, debtor-in-possession, assignee for the benefit of creditors, liquidator, receiver or other representative of or successor to any beneficiary or any transferee of such Letter of Credit, including any arising in connection with any proceeding under any Debtor Relief Law; or

(v) any other circumstance or happening whatsoever, whether or not similar to any of the foregoing, including any other circumstance that might otherwise constitute a defense available to, or a discharge of, the Borrower.

The Borrower shall promptly examine a copy of each Letter of Credit and each amendment thereto that is delivered to it and, in the event of any claim of noncompliance with the Borrower's instructions or other irregularity, the Borrower will immediately notify the L/C Issuer. The Borrower shall be conclusively deemed to have waived any such claim against the L/C Issuer and its correspondents unless such notice is given as aforesaid.

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(f) Role of L/C Issuer. Each Lender and the Borrower agree that, in paying any drawing under a Letter of Credit, the L/C Issuer shall not have any responsibility to obtain any document (other than any sight draft, certificates and documents expressly required by the Letter of Credit) or to ascertain or inquire as to the validity or accuracy of any such document or the authority of the Person executing or delivering any such document. None of the L/C Issuer, any Agent-Related Person nor any of the respective correspondents, participants or assignees of the L/C Issuer shall be liable to any Lender for (i) any action taken or omitted in connection herewith at the request or with the approval of the Lenders or the Required Lenders, as applicable, (ii) any action taken or omitted in the absence of gross negligence or willful misconduct or (iii) the due execution, effectiveness, validity or enforceability of any document or instrument related to any Letter of Credit or Letter of Credit Application. The Borrower hereby assumes all risks of the acts or omissions of any beneficiary or transferee with respect to its use of any Letter of Credit; provided, however, that this assumption is not intended to, and shall not, preclude the Borrower's pursuing such rights and remedies as it may have against the beneficiary or transferee at law or under any other agreement. None of the L/C Issuer, any Agent-Related Person, nor any of the respective correspondents, participants or assignees of the L/C Issuer, shall be liable or responsible for any of the matters described in clauses (i) through (v) of Section 2.2(e). In furtherance and not in limitation of the foregoing, the L/C Issuer may accept documents that appear on their face to be in order, without responsibility for further investigation and the L/C Issuer shall not be responsible for the validity or sufficiency of any instrument transferring or assigning or purporting to transfer or assign a Letter of Credit or the rights or benefits thereunder or proceeds thereof, in whole or in part, which may prove to be invalid or ineffective for any reason.

(g) Cash Collateral. If, as of the Letter of Credit Expiration Date, any Letter of Credit for any reason remains outstanding and partially or wholly undrawn, the Borrower shall immediately Cash Collateralize the then aggregate principal amount of all L/C Obligations (in an amount equal to such aggregate principal amount determined as of the Letter of Credit Expiration Date). The Borrower hereby grants to the Administrative Agent, for the benefit of the L/C Issuer and the Lenders, a security interest in all such cash, deposit accounts and all balances therein and all proceeds of the foregoing. Cash collateral shall be maintained in blocked, non-interest bearing deposit accounts at Bank of America.

(h) Applicability of ISP98 and UCP. Unless otherwise expressly agreed by the L/C Issuer and the Borrower when a Letter of Credit is issued (including any such agreement applicable to an Existing Letter of Credit), the rules of the "International Standby Practices 1998" published by the Institute of International Banking Requirement of Law & Practice (or such later version thereof as may be in effect at the time of issuance) and the rules of the Uniform Customs and Practice for Documentary Credits, as most recently published by the International Chamber of Commerce (the "ICC") at the time of issuance (including the ICC decision published by the Commission on Banking Technique and Practice on April 6, 1998 regarding the European single currency
(euro)) shall apply to each Letter of Credit.

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(i) Fronting Fee and Documentary and Processing Charges Payable to L/C Issuer. The Borrower shall pay directly to the L/C Issuer for its own account a fronting fee with respect to each Letter of Credit in an amount equal to 0.125% times the daily maximum amount available to be drawn under such Letter of Credit (the "L/C Fronting Fee"). The L/C Fronting Fee shall be computed on a quarterly basis in arrears and shall be due and payable on the last Business Day of each fiscal quarter of the Borrower (as well as on the Letter of Credit Expiration Date) for the fiscal quarter (or portion thereof) then ending, beginning with the first of such dates to occur after the issuance of such Letter of Credit. In addition, the Borrower shall pay directly to the L/C Issuer for its own account the customary issuance, presentation, amendment and other processing fees, and other standard costs and charges, of the L/C Issuer relating to letters of credit as from time to time in effect. Such customary fees and standard costs and charges are due and payable on demand and are nonrefundable.

(j) Conflict with Letter of Credit Application. In the event of any conflict between the terms hereof and the terms of any Letter of Credit Application, the terms hereof shall control.

(k) Indemnification of L/C Issuer.

(i) In addition to its other obligations under this Credit Agreement, the Borrower hereby agrees to protect, indemnify, pay and hold the L/C Issuer harmless from and against any and all claims, demands, liabilities, damages, losses, costs, charges and expenses (including reasonable attorneys' fees) that the L/C Issuer may incur or be subject to as a consequence, direct or indirect, of (A) the issuance of any Letter of Credit or (B) the failure of the L/C Issuer to honor a drawing under a Letter of Credit as a result of any act or omission, whether rightful or wrongful, of any present or future de jure or de facto government or Governmental Authority (all such acts or omissions, herein called "Government Acts").

(ii) As between the Borrower and the L/C Issuer, the Borrower shall assume all risks of the acts, omissions or misuse of any Letter of Credit by the beneficiary thereof. In the absence of gross negligence or willful misconduct, the L/C Issuer shall not be responsible for: (A) the form, validity, sufficiency, accuracy, genuineness or legal effect of any document submitted by any party in connection with the application for and issuance of any Letter of Credit, even if it should in fact prove to be in any or all respects invalid, insufficient, inaccurate, fraudulent or forged; (B) the validity or sufficiency of any instrument transferring or assigning or purporting to transfer or assign any Letter of Credit or the rights or benefits thereunder or proceeds thereof, in whole or in part, that may prove to be invalid or ineffective for any reason; (C) failure of the beneficiary of a Letter of Credit to comply fully with conditions required in order to draw upon a Letter of Credit; (D) errors, omissions, interruptions or delays in transmission or delivery of any messages, by mail, cable, telegraph, telex or otherwise, whether or not they be in cipher; (E) errors in interpretation of technical terms; (F) any loss or delay in the transmission or otherwise of any document required in order to make a drawing under a Letter of Credit or of the proceeds thereof; and (G) any consequences arising from causes beyond the control of the L/C Issuer, including, without limitation, any Government Acts. None of the above shall affect, impair, or prevent the vesting of the L/C Issuer's rights or powers hereunder.

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(iii) In furtherance and extension and not in limitation of the specific provisions hereinabove set forth, any action taken or omitted by the L/C Issuer, under or in connection with any Letter of Credit or the related certificates, if taken or omitted in good faith, shall not put the L/ C Issuer under any resulting liability to the Borrower. It is the intention of the parties that this Credit Agreement shall be construed and applied to protect and indemnify the L/C Issuer against any and all risks involved in the issuance of the Letters of Credit, all of which risks are hereby assumed by the Borrower, including, without limitation, any and all risks of the acts or omissions, whether rightful or wrongful, of any present or future Government Acts. The L/C Issuer shall not, in any way, be liable for any failure by the L/C Issuer or anyone else to pay any drawing under any Letter of Credit as a result of any Government Acts or any other cause beyond the control of the L/C Issuer.

(iv) Nothing in this subsection (l) is intended to limit the reimbursement obligation of the Borrower contained in this Section 2.2. The obligations of the Borrower under this subsection (l) shall survive the termination of this Credit Agreement. No act or omission of any current or prior beneficiary of a Letter of Credit shall in any way affect or impair the rights of the L/ C Issuer to enforce any right, power or benefit under this Credit Agreement.

(l) Letter of Credit Amounts. Unless otherwise specified, all references herein to the amount of a Letter of Credit at any time shall be deemed to mean the maximum face amount of such Letter of Credit after giving effect to all increases thereof contemplated by such Letter of Credit or the Letter of Credit Application therefor, whether or not such maximum face amount is in effect at such time.

2.3 Continuations and Conversions.

Subject to the terms below, the Borrower shall have the option, on any Business Day prior to the Maturity Date, to continue existing Eurodollar Loans for a subsequent Interest Period, to convert Base Rate Loans into Eurodollar Loans or to convert Eurodollar Loans into Base Rate Loans. By no later than 11:00 a.m. (a) on the date of the requested conversion of a Eurodollar Loan to a Base Rate Loan and (b) three Business Days prior to the date of the requested continuation of a Eurodollar Loan or conversion of a Base Rate Loan to a Eurodollar Loan, the Borrower shall provide telephonic notice to the Administrative Agent, followed promptly by a written Notice of Continuation/Conversion in the form of Exhibit 2.3, setting forth whether the Borrower wishes to continue or convert such Revolving Loans. Notwithstanding anything herein to the contrary, (A) except as provided in Section 3.11, Eurodollar Loans may only be continued or converted into Base Rate Loans on the last day of the Interest Period applicable thereto, (B) Eurodollar Loans may not be continued nor may Base Rate Loans be converted into Eurodollar Loans during the existence and continuation of a Default or an Event of Default and (C) any request to continue a Eurodollar Loan that fails to comply with the terms hereof or any failure to request a continuation of a Eurodollar Loan at the end of an Interest Period shall be deemed a request to convert such Eurodollar Loan to a Base Rate Loan on the last day of the applicable Interest Period.

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2.4 Minimum Amounts.

Each request for a borrowing, conversion or continuation shall be subject to the requirements that (a) each Eurodollar Loan shall be in a minimum amount of $5,000,000 and in integral multiples of $1,000,000 in excess thereof,
(b) each Base Rate Loan shall be in a minimum amount of $3,000,000 and in integral multiples of $100,000 in excess thereof (or the remaining amount of outstanding Revolving Loans) and (c) no more than five Eurodollar Loans shall be outstanding hereunder at any one time. For the purposes of this Section 2.4, separate Eurodollar Loans that begin and end on the same date, as well as Eurodollar Loans that begin and end on different dates, shall all be considered as separate Eurodollar Loans.

SECTION 3

GENERAL PROVISIONS APPLICABLE
TO REVOLVING LOANS

3.1 Interest.

(a) Interest Rate. Subject to Sections 3.1(b), (i) all Base Rate Loans shall accrue interest at the Base Rate and (ii) all Eurodollar Loans shall accrue interest at the Adjusted Eurodollar Rate.

(b) Default Rate of Interest. After the occurrence, and during the continuation, of an Event of Default, the principal of and, to the extent permitted by Law, interest on the Revolving Loans and any other amounts owing hereunder or under the other Credit Documents (including without limitation fees and expenses) shall bear interest, payable on demand, at the Default Rate.

(c) Interest Payments. Interest on Revolving Loans shall be due and payable in arrears on each Interest Payment Date.

3.2 Payments Generally.

(a) No Deductions; Place and Time of Payments. All payments to be made by the Borrower shall be made without condition or deduction for any counterclaim, defense, recoupment or setoff. Except as otherwise expressly provided herein, all payments by the Borrower hereunder shall be made to the Administrative Agent, for the account of the respective Lenders to which such payment is owed, at the Administrative Agent's Office in Dollars and in immediately available funds not later than 2:00 p.m. on the date specified herein. The Administrative Agent will promptly distribute to each Lender its Pro Rata Share (or other applicable share as provided herein) of such payment in like funds as received by wire transfer to such Lender's Lending Office. All payments received by the Administrative Agent after 2:00 p.m. shall deemed received on the next succeeding Business Day and any applicable interest or fee shall continue to accrue.

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(b) Payment Dates. Subject to the definition of "Interest Period," if any payment to be made by the Borrower shall come due on a day other than a Business Day, payment shall be made on the next following Business Day, and such extension of time shall be reflected in computing interest or fees, as the case may be.

(c) Advances by Administrative Agent. Unless the Borrower or any Lender has notified the Administrative Agent, prior to the date any payment is required to be made by it to the Administrative Agent hereunder, that the Borrower or such Lender, as the case may be, will not make such payment, the Administrative Agent may assume that the Borrower or such Lender, as the case may be, has timely made such payment and may (but shall not be so required to), in reliance thereon, make available a corresponding amount to the Person entitled thereto. If and to the extent that such payment was not in fact made to the Administrative Agent in immediately available funds, then:

(i) if the Borrower failed to make such payment, each Lender shall forthwith on demand repay to the Administrative Agent the portion of such assumed payment that was made available to such Lender in immediately available funds, together with interest thereon in respect of each day from and including the date such amount was made available by the Administrative Agent to such Lender to the date such amount is repaid to the Administrative Agent in immediately available funds at the Federal Funds Rate from time to time in effect; and

(ii) if any Lender failed to make such payment, such Lender shall forthwith on demand pay to the Administrative Agent the amount thereof in immediately available funds, together with interest thereon for the period from the date such amount was made available by the Administrative Agent to the Borrower to the date such amount is recovered by the Administrative Agent (the "Compensation Period") at a rate per annum equal to the Federal Funds Rate from time to time in effect. If such Lender pays such amount to the Administrative Agent, then such amount shall constitute such Lender's Revolving Loan included in the applicable Borrowing. If such Lender does not pay such amount forthwith upon the Administrative Agent's demand therefor, the Administrative Agent may make a demand therefor upon the Borrower, and the Borrower shall pay such amount to the Administrative Agent, together with interest thereon for the Compensation Period at a rate per annum equal to the rate of interest applicable to such Borrowing. Nothing herein shall be deemed to relieve any Lender from its obligation to fulfill its Commitment or to prejudice any rights which the Administrative Agent or the Borrower may have against any Lender as a result of any default by such Lender hereunder.

A notice of the Administrative Agent to any Lender or the Borrower with respect to any amount owing under this subsection (c) shall be conclusive, absent manifest error.

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(d) Several Obligations. The obligations of the Lenders hereunder to make Revolving Loans and to fund or purchase Participation Interests are several and not joint. The failure of any Lender to make any Revolving Loan or to fund or purchase any Participation Interest on any date required hereunder shall not relieve any other Lender of its corresponding obligation to do so on such date, and no Lender shall be responsible for the failure of any other Lender to so make its Revolving Loan or fund or purchase its Participation Interest.

(e) Funding Offices. Nothing herein shall be deemed to obligate any Lender to obtain the funds for any Revolving Loan in any particular place or manner or to constitute a representation by any Lender that it has obtained or will obtain the funds for any Revolving Loan in any particular place or manner.

3.3 Prepayments.

(a) Voluntary Prepayments. The Borrower shall have the right to prepay the Revolving Loans in whole or in part from time to time without premium or penalty; provided, however, that (i) all prepayments under this Section 3.3(a) shall be subject to Section 3.14, (ii) Eurodollar Loans may only be prepaid on three Business Days' prior written notice to the Administrative Agent, (iii) each such partial prepayment of Eurodollar Loans shall be in the minimum principal amount of $5,000,000 and integral multiples of $1,000,000 and (iv) each such partial prepayment of Base Rate Loans shall be in the minimum principal amount of $500,000 and integral multiples of $100,000 or, in the case of clauses (iii) and (iv), if less than such minimum amounts, the entire principal amount thereof then outstanding. Amounts prepaid pursuant to this Section 3.3(a) shall be applied as the Borrower may elect based on the Lenders' Pro Rata Shares; provided, however, if the Borrower fails to specify, such prepayment shall be applied by the Administrative Agent, subject to Section 3.7, in such manner as it deems reasonably appropriate.

(b) Mandatory Prepayments. If at any time (i) the sum of the aggregate principal amount of Revolving Loans outstanding plus the aggregate principal amount of L/C Obligations outstanding exceeds the Revolving Committed Amount or (ii) the aggregate principal amount of L/C Obligations outstanding exceeds the Letter of Credit Sublimit, the Borrower shall immediately make a principal payment to the Administrative Agent and/or Cash Collateralize outstanding L/C Obligations in a manner, in an amount and in Dollars as is necessary to be in compliance with Sections 2.1 and 2.2, as applicable, and as directed by the Administrative Agent. All amounts required to be prepaid pursuant to this Section 3.3(b) shall be applied first to Base Rate Loans, second to Eurodollar Loans in direct order of Interest Period maturities and third to Cash Collateralize outstanding L/C Obligations. All prepayments pursuant to this Section 3.3(b) shall be subject to Section 3.14.

3.4 Fees.

(a) Commitment Fees. In consideration of the Revolving Committed Amount being made available by the Lenders hereunder, the Borrower agrees to pay to the Administrative Agent, for the pro rata benefit of each Lender based on its Pro Rata Share, a per annum fee

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equal to the daily average sum of the Applicable Percentage for Commitment Fees for each day during the period of determination multiplied by the Unused Revolving Commitment for each such day (the "Commitment Fees"). The Commitment Fees shall commence to accrue on the Closing Date and shall be due and payable in arrears on the last Business Day of each fiscal quarter of the Borrower (as well as on the Maturity Date and on any date that the Revolving Committed Amount is reduced) for the fiscal quarter (or portion thereof) then ending, beginning with the first of such dates to occur after the Closing Date.

(b) Utilization Fees. If at any time the aggregate principal amount of outstanding Revolving Loans exceeds an amount equal to thirty-three percent (33%) of the Revolving Committed Amount, the Borrower shall pay to the Administrative Agent, for the ratable benefit of the Lenders, a utilization fee (the "Utilization Fees") equal to the product of (i) the average daily aggregate principal amount of outstanding Revolving Loans, calculated from the date the aggregate principal amount of outstanding Revolving Loans exceeds an amount equal to thirty-three percent (33%) of the Revolving Committed Amount but excluding the date the aggregate principal amount of outstanding Revolving Loans falls below an amount equal to thirty-three percent (33%), times (ii) a per annum percentage equal to the Applicable Percentage for Utilization Fees. The Utilization Fees shall be payable in arrears on the last Business Day of each fiscal quarter of the Borrower (as well as on the Maturity Date and on any date that the Revolving Committed Amount is reduced) for the fiscal quarter (or portion thereof) then ending, beginning with the first of such dates to occur after the Closing Date.

(c) L/C Fees. The Borrower shall pay to the Administrative Agent for the account of each Lender in accordance with its Pro Rata Share a fee for each Letter of Credit equal to the Applicable Percentage for L/C Fees times the daily maximum amount available to be drawn under such Letter of Credit (the "L/C Fees"). The L/C Fees shall be computed on a quarterly basis in arrears and shall be due and payable on the last Business Day of each fiscal quarter of the Borrower (as well as on the Letter of Credit Expiration Date) for the fiscal quarter (or portion thereof) then ending, beginning with the first of such dates to occur after the issuance of such Letter of Credit.

(d) Administrative Fees. The Borrower agrees to pay to the Administrative Agent, for its own account, an annual fee as agreed to between the Borrower and the Administrative Agent (the "Administrative Fees") in the Fee Letter.

3.5 Payment in full at Maturity.

On the Maturity Date, the entire outstanding principal balance of all Revolving Loans, together with accrued but unpaid interest and all fees and other sums owing under the Credit Documents, shall be due and payable in full, unless accelerated sooner pursuant to Section 9.2; provided that if the Maturity Date is not a Business Day, then such principal, interest, fees and other sums shall be due and payable in full on the next preceding Business Day.

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3.6 Computations of Interest and Fees.

(a) Calculation of Interest. Except for Base Rate Loans that are based upon the Prime Rate, in which case interest shall be computed on the basis of the actual number of days elapsed over a year of 365 or 366 days, as the case may be, all computations of interest and fees hereunder shall be made on the basis of the actual number of days elapsed over a year of 360 days. Interest shall accrue from and including the first date of Borrowing (or continuation or conversion) to but excluding the last day occurring in the period for which such interest is payable.

(b) Usury. It is the intent of the Lenders and the Borrower to conform to and contract in strict compliance with applicable usury Law from time to time in effect. All agreements between the Lenders and the Borrower are hereby limited by the provisions of this subsection which shall override and control all such agreements, whether now existing or hereafter arising and whether written or oral. In no way, nor in any event or contingency (including but not limited to prepayment or acceleration of the maturity of any Borrower Obligation), shall the interest taken, reserved, contracted for, charged, or received under this Credit Agreement, under the Revolving Notes or otherwise, exceed the maximum nonusurious amount permissible under applicable Law. If, from any possible construction of any of the Credit Documents or any other document, interest would otherwise be payable in excess of the maximum nonusurious amount, any such construction shall be subject to the provisions of this subsection and such documents shall be automatically reduced to the maximum nonusurious amount permitted under applicable Law, without the necessity of execution of any amendment or new document. If any Lender shall ever receive anything of value which is characterized as interest on the Revolving Loans under applicable Law and which would, apart from this provision, be in excess of the maximum nonusurious amount, an amount equal to the amount which would have been excessive interest shall, without penalty, be applied to the reduction of the principal amount owing on the Revolving Loans and not to the payment of interest, or refunded to the Borrower or the other payor thereof if and to the extent such amount which would have been excessive exceeds such unpaid principal amount of the Revolving Loans. The right to demand payment of the Revolving Loans or any other Indebtedness evidenced by any of the Credit Documents does not include the right to accelerate the payment of any interest which has not otherwise accrued on the date of such demand, and the Lenders do not intend to charge or receive any unearned interest in the event of such demand. All interest paid or agreed to be paid to the Lenders with respect to the Revolving Loans shall, to the extent permitted by applicable Law, be amortized, prorated, allocated, and spread throughout the full stated term (including any renewal or extension) of the Revolving Loans so that the amount of interest on account of the Revolving Loans does not exceed the maximum nonusurious amount permitted by applicable Law.

3.7 Pro Rata Treatment.

Except to the extent otherwise provided herein, each Borrowing, each payment or prepayment of principal of any Revolving Loan, each L/C Credit Extension, each payment of interest, each payment of fees (other than administrative fees paid to the Administrative Agent and fronting, documentary and processing fees paid to the L/C Issuer), each conversion or continuation of any Revolving Loans and each reduction in the Revolving Committed Amount, shall be allocated pro rata among the relevant Lenders in accordance with their Pro Rata Shares; provided that, if any Lender shall have failed to pay its Pro Rata Share of any Revolving Loan or fund or purchase its Participation Interest, then

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any amount to which such Lender would otherwise be entitled pursuant to this
Section 3.7 shall instead be payable to the Administrative Agent until the share of such Revolving Loan or such Participation Interest not funded or purchased by such Lender has been repaid. In the event any principal, interest, fee or other amount paid to any Lender pursuant to this Credit Agreement or any other Credit Document is rescinded or must otherwise be returned by the Administrative Agent,
(a) such principal, interest, fee or other amount that had been satisfied by such payment shall be revived, reinstated and continued in full force and effect as if such payment had not occurred and (b) such Lender shall, upon the request of the Administrative Agent, repay to the Administrative Agent the amount so paid to such Lender, with interest for the period commencing on the date such payment is returned by the Administrative Agent until the date the Administrative Agent receives such repayment at a rate per annum equal to the Federal Funds Rate if repaid within two (2) Business Days after such request and thereafter the Base Rate.

3.8 Sharing of Payments.

The Lenders agree among themselves that, except to the extent otherwise provided herein, in the event that any Lender shall obtain payment in respect of any Revolving Loan, any L/C Obligations or any other obligation owing to such Lender under this Credit Agreement through the exercise of a right of setoff, banker's lien or counterclaim, or pursuant to a secured claim under Section 506 of the Bankruptcy Code or other security or interest arising from, or in lieu of, such secured claim, received by such Lender under any applicable Debtor Relief Law or other similar Law or otherwise, or by any other means, in excess of its Pro Rata Share of such payment as provided for in this Credit Agreement, such Lender shall promptly pay in cash or purchase from the other Lenders a participation in such Revolving Loans, L/C Obligations and other obligations in such amounts, and make such other adjustments from time to time, as shall be equitable to the end that all Lenders share such payment in accordance with their Pro Rata Shares. The Lenders further agree among themselves that if payment to a Lender obtained by such Lender through the exercise of a right of setoff, banker's lien, counterclaim or other event as aforesaid shall be rescinded or must otherwise be returned, each Lender which shall have shared the benefit of such payment shall, by payment in cash or a repurchase of a participation theretofore sold, return its share of that benefit (together with its share of any accrued interest payable with respect thereto) to each Lender whose payment shall have been rescinded or otherwise returned. The Borrower agrees that (a) any Lender so purchasing such a participation may, to the fullest extent permitted by Law, exercise all rights of payment, including setoff, banker's lien or counterclaim, with respect to such participation as fully as if such Lender were a holder of such Revolving Loan, L/C Obligations or other obligation in the amount of such participation and (b) the Borrower Obligations that have been satisfied by a payment that has been rescinded or otherwise returned shall be revived, reinstated and continued in full force and effect as if such payment had not occurred. Except as otherwise expressly provided in this Credit Agreement, if any Lender or the Administrative Agent shall fail to remit to any other Lender an amount payable by such Lender or the Administrative Agent to such other Lender pursuant to this Credit Agreement on the date when such amount is due, such payments shall be made together with interest thereon for each date from the date such amount is due until the date such amount is paid to the Administrative Agent or such other Lender at a rate per annum equal to the Federal Funds Rate. If under any applicable Debtor Relief Law or other similar Law, any Lender receives a secured claim in lieu of a setoff to which this Section 3.8 applies, such Lender shall, to the extent practicable, exercise its rights in respect of such secured claim in a manner consistent with the rights of the Lenders under this Section 3.8 to share in the benefits of any recovery on such secured claim.

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3.9 Capital Adequacy.

If any Lender determines that the introduction after the Closing Date of any Law, rule or regulation or other Requirement of Law regarding capital adequacy or any change therein or in the interpretation thereof, or compliance by such Lender (or its Lending Office) therewith, has or would have the effect of reducing the rate of return on the capital or assets of such Lender or any corporation controlling such Lender as a consequence of such Lender's obligations hereunder (taking into consideration its policies with respect to capital adequacy and such Lender's desired return on capital), then from time to time upon demand of such Lender (with a copy of such demand to the Administrative Agent), the Borrower shall pay to such Lender such additional amounts as will compensate such Lender for such reduction.

3.10 Eurodollar Provisions.

If the Administrative Agent determines (which determination shall be conclusive and binding upon the Borrower) in connection with any request for a Eurodollar Loan or a conversion to or continuation thereof that (i) deposits in Dollars are not being offered to banks in the applicable offshore interbank market for the applicable amount and Interest Period of such Eurodollar Loan, (ii) adequate and reasonable means do not exist for determining the Eurodollar Rate for such Eurodollar Loan, or (iii) the Eurodollar Rate for such Eurodollar Loan in such does not adequately and fairly reflect the cost to the Lenders of funding such Eurodollar Loan, the Administrative Agent will promptly notify the Borrower and the Lenders. Thereafter, the obligation of the Lenders to make or maintain Eurodollar Loans shall be suspended until the Administrative Agent revokes such notice. Upon receipt of such notice, the Borrower may revoke any pending Notice of Borrowing or Notice of Continuation/Conversion with respect to Eurodollar Loans or, failing that, will be deemed to have converted such request into a request for a Borrowing of or, to the extent permitted hereunder, conversion into a Base Rate Loan in the amount specified therein.

3.11 Illegality.

If any Lender determines that any Requirement of Law has made it unlawful, or that any Governmental Authority has asserted that it is unlawful, for any Lender or its applicable Lending Office to make, maintain or fund Eurodollar Loans, or materially restricts the authority of such Lender to purchase or sell, or to take deposits of Dollars in the London interbank market, or to determine or charge interest rates based upon the Eurodollar Rate, then, on notice thereof by such Lender to the Borrower through the Administrative Agent, any obligation of such Lender to make or continue Eurodollar Loans or to convert Base Rate Loans to Eurodollar Loans shall be suspended until such Lender notifies the Administrative Agent and the Borrower that the circumstances giving rise to such determination no longer exist. Upon receipt of such notice, the Borrower shall, upon demand to the Borrower from such Lender (with a copy to the Administrative Agent), prepay or, if applicable, convert all Eurodollar Loans of such Lender to Base Rate Loans, either on the last day of the Interest Period

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thereof, if such Lender may lawfully continue to maintain such Eurodollar Loans to such day, or immediately, if such Lender may not lawfully continue to maintain such Eurodollar Loans. Upon any such prepayment or conversion, the Borrower shall also pay interest on the amount so prepaid or converted, together with any amounts due with respect thereto pursuant to Section 3.14.

3.12 Requirements of Law; Reserves on Eurodollar Loans.

(a) Changes in Law. If any Lender determines that as a result of the introduction of or any change in, or in the interpretation of, any Requirement of Law, or such Lender's compliance therewith, there shall be any increase in the cost to such Lender of agreeing to make or making, funding or maintaining Eurodollar Loans, or a reduction in the amount received or receivable by such Lender in connection with any of the foregoing (excluding for purposes of this Section 3.12 any such increased costs or reduction in amount resulting from (i) Taxes or Other Taxes (as to which Section 3.13 shall govern) and (ii) reserve requirements contemplated by subsection (b) below), then from time to time, upon demand of such Lender (through the Administrative Agent), the Borrower shall pay to such Lender such additional amounts as will compensate such Lender for such increased cost or reduction in yield.

(b) Reserves. The Borrower shall pay to each Lender (to the extent such Lender has not otherwise been compensated therefor hereunder), as long as such Lender shall be required to maintain reserves with respect to liabilities or assets consisting of or including Eurodollar funds or deposits (currently known as "Eurodollar liabilities"), additional interest on the unpaid principal amount of each Eurodollar Loan equal to the actual costs of such reserves allocated to such Loan by such Lender (as determined by such Lender in good faith, which determination shall be conclusive absent demonstrable error), which shall be due and payable on each date on which interest is payable on such Loan; provided that the Borrower shall have received at least 15 days' prior notice (with a copy to the Administrative Agent) of such additional interest from such Lender. If a Lender fails to give notice 15 days prior to the relevant Interest Payment Date, such additional interest shall be due and payable 15 days from receipt of such notice.

3.13 Taxes.

(a) Payment of Taxes. Any and all payments by the Borrower to or for the account of the Administrative Agent or any Lender under any Credit Document shall be made free and clear of and without deduction for any and all present or future income, stamp or other taxes, duties, levies, imposts, deductions, assessments, fees, withholdings or similar charges, and all liabilities with respect thereto, but excluding, in the case of the Administrative Agent and each Lender, taxes imposed on or measured by its net income, and franchise taxes imposed on it (in lieu of net income taxes), by the jurisdiction (or any political subdivision thereof) under the Laws of which the Administrative Agent or such Lender, as the case may be, is organized or maintains its Lending Office (all such non-excluded present or future income, stamp or other taxes, duties, levies, imposts, deductions, assessments, fees, withholdings or similar charges, and liabilities being hereinafter referred to as "Taxes"). If the Borrower shall be required by any

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Requirement of Law to deduct any Taxes from or in respect of any sum payable under any Credit Document to the Administrative Agent or any Lender, (i) the sum payable shall be increased as necessary so that after making all required deductions (including deductions applicable to additional sums payable under this Section 3.13(a)), the Administrative Agent or such Lender, as the case may be, receives an amount equal to the sum it would have received had no such deductions been made, (ii) the Borrower shall make such deductions, (iii) the Borrower shall pay the full amount deducted to the relevant taxation authority or other Governmental Authority in accordance with applicable Requirements of Law, and (iv) within 30 days after the date of such payment, the Borrower shall furnish to the Administrative Agent (which shall forward the same to such Lender, if applicable) the original or a certified copy of a receipt evidencing payment thereof, to the extent such receipt is issued therefor, or other written proof of payment thereof that is reasonably satisfactory to the Administrative Agent.

(b) Additional Taxes. In addition, the Borrower agrees to pay any and all present or future stamp, court or documentary taxes and any other excise or property taxes or charges or similar levies which arise from any payment made under any Credit Document or from the execution, delivery, performance, enforcement or registration of, or otherwise with respect to, any Credit Document (hereinafter referred to as "Other Taxes").

(c) No Deduction for Taxes. If the Borrower shall be required to deduct or pay any Taxes or Other Taxes from or in respect of any sum payable under any Credit Document to the Administrative Agent or any Lender, the Borrower shall also pay to the Administrative Agent (for the account of such Lender) or to such Lender, at the time interest is paid, such additional amount that such Lender specifies as necessary to preserve the after-tax yield (after factoring in all taxes, including taxes imposed on or measured by net income) such Lender would have received if such Taxes or Other Taxes had not been imposed.

(d) Indemnification. The Borrower agrees to indemnify the Administrative Agent and each Lender for (i) the full amount of Taxes and Other Taxes (including any Taxes or Other Taxes imposed or asserted by any jurisdiction on amounts payable under this Section 3.13(d)) paid by the Administrative Agent and such Lender, and (ii) any liability (including penalties, interest and expenses) arising therefrom or with respect thereto.

(e) Exemption from Taxes. In the case of any payment hereunder or under any other Credit Document by or on behalf of the Borrower through an account or branch outside the United States, or on behalf of the Borrower by a payor that is not a United States person, if the Borrower determines that no taxes are payable in respect thereof, the Borrower shall furnish, or shall cause such payor to furnish, to the Administrative Agent, an opinion of counsel reasonably acceptable to the Administrative Agent stating that such payment is exempt from Taxes. For purposes of this subsection (e), the terms "United States" and "United States person" shall have the meanings specified in Section 7701 of the Code.

(f) Foreign Lenders. Each Lender that is a foreign corporation, foreign partnership or foreign trust within the meaning of the Code (a "Foreign Lender") shall deliver to the Administrative Agent, prior to receipt of any payment subject to withholding under the Code, two duly signed completed copies of either IRS Form W-8BEN or any

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successor thereto (relating to such Lender and entitling it to an exemption from, or reduction of, withholding tax on all payments to be made to such Lender by the Borrower pursuant to this Credit Agreement), as appropriate, or IRS Form W-8ECI or any successor thereto (relating to all payments to be made to such Lender by the Borrower pursuant to this Credit Agreement) or such other evidence satisfactory to the Borrower and the Administrative Agent that such Lender is entitled to an exemption from, or reduction of, United States withholding tax. Thereafter and from time to time, each such Lender shall (i) promptly submit to the Administrative Agent such additional duly completed and signed copies of one of such forms (or such successor forms as shall be adopted from time to time by the relevant United States taxing authorities), as appropriate, as may reasonably be requested by the Borrower or the Administrative Agent and then be available under then current United States Laws and regulations to avoid, or such evidence as is satisfactory to the Borrower and the Administrative Agent of any available exemption from or reduction of, United States withholding taxes in respect of all payments to be made to such Lender by the Borrower pursuant to this Credit Agreement, (ii) promptly notify the Administrative Agent of any change in circumstances which would modify or render invalid any claimed exemption or reduction, and (iii) take such steps as shall not be materially disadvantageous to it, in the reasonable judgment of such Lender, and as may be reasonably necessary (including the re-designation of its Lending Office) to avoid any Requirement of Law that the Borrower make any deduction or withholding for taxes from amounts payable to such Lender. If the forms or other evidence provided by such Lender at the time such Lender first becomes a party to this Credit Agreement indicate a United States interest withholding tax rate in excess of zero, withholding tax at such rate shall be considered excluded from Taxes unless and until such Lender provides the appropriate forms certifying that a lesser rate applies, whereupon withholding tax at such lesser rate only shall be considered excluded from Taxes for periods governed by such forms; provided, however, that, if at the date of any assignment pursuant to which a Lender becomes a party to this Credit Agreement, the assignor Lender was entitled to payments under Section 3.13(a) in respect of United States withholding tax with respect to interest paid at such date, then, to such extent, the term Taxes shall include (in addition to withholding taxes that may be imposed in the future or other amounts otherwise includable in Taxes) United States withholding tax, if any, applicable with respect to the assignee Lender on such date. If such Lender fails to deliver the above forms or other evidence, then the Administrative Agent may withhold from any interest payment to such Lender an amount equal to the applicable withholding tax imposed by Sections 1441 and 1442 of the Code, without reduction. If any Governmental Authority asserts that the Administrative Agent did not properly withhold any tax or other amount from payments made in respect of such Lender, such Lender shall indemnify the Administrative Agent therefor, including all penalties and interest, any taxes imposed by any jurisdiction on the amounts payable to the Administrative Agent under this Section 3.13(f), and costs and expenses (including the reasonable fees and expenses of legal counsel) of the Administrative Agent. For any period with respect to which a Lender has failed to provide the Borrower with the above forms or other evidence (other than if such failure is due to a change in the applicable Law, or in the interpretation or application thereof, occurring after the date on which such form or other evidence originally was required to be provided or if such form or other evidence otherwise is not required), such Lender shall not be entitled to indemnification under subsection
(a) or (c) of this Section 3.13 with respect to Taxes imposed by the United States by reason of such failure; provided, however, that should

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a Lender become subject to Taxes because of its failure to deliver such form or other evidence required hereunder, the Borrower shall take such steps as such Lender shall reasonably request to assist such Lender in recovering such Taxes. The obligation of the Lenders under this Section 3.13(f) shall survive the payment of all Borrower Obligations and the resignation or replacement of the Administrative Agent.

(g) Reimbursement. In the event that an additional payment is made under Section 3.13(a) or (c) for the account of any Lender and such Lender, in its reasonable judgment, determines that it has finally and irrevocably received or been granted a credit against or release or remission for, or repayment of, any tax paid or payable by it in respect of or calculated with reference to the deduction or withholding giving rise to such payment, such Lender shall, to the extent that it determines that it can do so without prejudice to the retention of the amount of such credit, relief, remission or repayment, pay to the Borrower such amount as such Lender shall, in its reasonable judgment, have determined to be attributable to such deduction or withholding and which will leave such Lender (after such payment) in no worse position than it would have been in if the Borrower had not been required to make such deduction or withholding. Nothing herein contained shall interfere with the right of a Lender to arrange its tax affairs in whatever manner it thinks fit nor oblige any Lender to claim any tax credit or to disclose any information relating to its tax affairs or any computations in respect thereof or require any Lender to do anything that would prejudice its ability to benefit from any other credits, reliefs, remissions or repayments to which it may be entitled.

3.14 Compensation.

Upon the written demand of any Lender, the Borrower shall promptly compensate such Lender for and hold such Lender harmless from any loss, cost or expense incurred by it as a result of:

(a) any continuation, conversion, payment or prepayment of any Eurodollar Loan on a day other than the last day of the Interest Period for such Eurodollar Loan (whether voluntary, mandatory, automatic, by reason of acceleration, or otherwise); or

(b) any failure by a Borrower (for a reason other than the failure of such Lender to make a Eurodollar Loan) to prepay, borrow, continue or convert any Eurodollar Loan on the date or in the amount previously requested by such Borrower.

The amount each such Lender shall be compensated pursuant to this Section 3.14 shall include, without limitation, (i) any loss incurred by such Lender in connection with the re-employment of funds prepaid, repaid, not borrowed or paid, as the case may be and (ii) any reasonable out-of-pocket expenses (including the reasonable fees and expenses of legal counsel) incurred and reasonably attributable thereto.

For purposes of calculating amounts payable by the Borrower to the Lenders under this Section 3.14, each Lender shall be deemed to have funded each Eurodollar Loan made by it at the Eurodollar Rate for such Loan by a matching deposit or other borrowing in the London interbank market for a comparable amount and for a comparable period, whether or not such Eurodollar Loan was in fact so funded.

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3.15 Determination and Survival of Provisions.

All determinations by the Administrative Agent or a Lender of amounts owing under Sections 3.9 through 3.14, inclusive, shall, absent manifest error, be conclusive and binding on the parties hereto and all amounts owing thereunder shall be due and payable within ten Business Days of demand therefor. In determining such amount, the Administrative Agent or such Lender may use any reasonable averaging and attribution methods. Section 3.9 through 3.14, inclusive, shall survive the termination of this Credit Agreement and the payment of all Borrower Obligations.

SECTION 4

CONDITIONS PRECEDENT TO CLOSING

4.1 Closing Conditions.

The obligation of the Lenders to enter into this Credit Agreement and make the initial Revolving Loans is subject to satisfaction of the following conditions:

(a) Executed Credit Documents. Receipt by the Administrative Agent of duly executed copies of: (i) this Credit Agreement, (ii) the Revolving Notes, and (iii) all other Credit Documents, each in form and substance reasonably acceptable to the Lenders in their sole discretion.

(b) Authority Documents. Receipt by the Administrative Agent of the following:

(i) Organizational Documents. Copies of the articles of incorporation of the Borrower certified to be true and complete as of a recent date by the appropriate Governmental Authority of the state or other jurisdiction of its formation and copies of the bylaws of the Borrower certified by a secretary or assistant secretary (or the equivalent) of the Borrower to be true and correct as of the Closing Date.

(ii) Resolutions. Copies of resolutions of the board of directors of the Borrower approving and adopting this Credit Agreement and the other Credit Documents to which it is a party, the transactions contemplated herein and therein and authorizing execution and delivery hereof and thereof, certified by a secretary or assistant secretary (or the equivalent) of the Borrower to be true and correct and in full force and effect as of the Closing Date.

(iii) Good Standing. Copies of certificates of good standing, existence or its equivalent with respect to the Borrower certified as of a recent date by the appropriate Governmental Authority of the state or other jurisdiction of its formation.

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(iv) Incumbency. An incumbency certificate of the Borrower certified by a secretary or assistant secretary (or the equivalent) of the Borrower to be true and correct as of the Closing Date.

(c) Opinions of Counsel. Receipt by the Administrative Agent of opinions of counsel from outside counsel to the Borrower, in form and substance acceptable to the Administrative Agent, addressed to the Administrative Agent and the Lenders and dated as of the Closing Date.

(d) Financial Statements. Receipt by the Administrative Agent of a copy of (i) the annual consolidated financial statements
(including balance sheets, income statements and cash flow statements) of the Borrower and its Subsidiaries for fiscal years 2000 and 2001, audited by independent public accountants of recognized national standing, (ii) the consolidated balance sheet and income statement of the Borrower and its Subsidiaries for the fiscal quarter ended September 30, 2002, together with the related consolidated statement of income for such fiscal quarter and a year to date statement of cash flows and (iii) such other financial information regarding the Borrower as the Administrative Agent may reasonably request.

(e) Due Diligence. The Administrative Agent and the Lenders shall have completed all due diligence with respect to the Borrower and its Subsidiaries and the transactions contemplated by this Credit Agreement and the other Credit Documents, in scope and determination reasonably satisfactory to the Administrative Agent and the Lenders.

(f) Material Adverse Effect. Since December 31, 2001, there shall have been no development or event relating to or affecting the Borrower or any of its Subsidiaries that has had or could be reasonably expected to have a Material Adverse Effect and no Material Adverse Change in the facts and information regarding the Borrower and its Subsidiaries as represented to date.

(g) Absence of Market Disruption. There shall not have occurred a material adverse change in or material disruption of conditions in the financial, banking or capital markets which the Administrative Agent and the Arranger, in their sole discretion, deem material in connection with the syndication of the Credit Agreement.

(h) Litigation. There shall not exist any material order, decree, judgment, ruling or injunction or any material pending or threatened action, suit, investigation or proceeding against the Borrower or any of its Subsidiaries.

(i) Consents. All necessary governmental, shareholder and third party consents and approvals, if any, with respect to this Credit Agreement and the Credit Documents and the transactions contemplated herein and therein have been received and no condition or Requirement of Law exists which would reasonably be likely to restrain, prevent or impose any material adverse conditions on the transactions contemplated hereby and by the other Credit Documents.

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(j) Officer's Certificates. Receipt by the Administrative Agent of a certificate or certificates executed by an Authorized Officer of the Borrower as of the Closing Date stating that (i) the Borrower and each of its Subsidiaries are in compliance in all material respects with all existing material financial obligations and all material Requirements of Law, (ii) there does not exist any material order, decree, judgment, ruling or injunction or any material pending or threatened action, suit, investigation or proceeding against the Borrower or any of its Subsidiaries, (iii) the financial statements and information delivered to the Administrative Agent on or before the Closing Date were prepared in good faith and in accordance with GAAP and (iv) immediately after giving effect to this Credit Agreement, the other Credit Documents and all the transactions contemplated herein or therein to occur on such date, (A) the Borrower is Solvent, (B) no Default or Event of Default exists, (C) all representations and warranties contained herein and in the other Credit Documents are true and correct in all material respects, (D) since December 31, 2001, there has been no development or event relating to or affecting the Borrower or any of its Subsidiaries that has had or could be reasonably expected to have a Material Adverse Effect and there exists no event, condition or state of facts that could result in or reasonably be expected to result in a Material Adverse Change and (E) the Borrower is in compliance with each of the financial covenants set forth in Section 7.2, as of September 30, 2002, as demonstrated in Covenant Compliance Worksheets attached to such certificate.

(k) Existing Credit Agreement. Receipt by the Administrative Agent of evidence that all amounts outstanding under the Existing Credit Agreement have been paid in full and the commitments thereunder terminated or that such payments will be made and commitments terminated simultaneously with the execution and delivery of the Credit Documents.

(l) Fees and Expenses. Unless waived by the Person entitled thereto, payment by the Borrower of all fees and expenses owed by them to the Administrative Agent, the Arranger and the Lenders on or before the Closing Date, including, without limitation, as set forth in the Fee Letter.

(m) Other. Receipt by the Lenders of such other documents, instruments, agreements or information as reasonably requested by any Lender.

SECTION 5

CONDITIONS TO ALL EXTENSIONS OF CREDIT

5.1 Funding Requirements.

In addition to the conditions precedent stated elsewhere herein, the Lenders shall not be obligated to make Revolving Loans and the L/C Issuer shall not be obligated to issue Letters of Credit unless:

(a) Notice. The Borrower shall have delivered (i) in the case of any new Revolving Loan, a Notice of Borrowing, duly executed and completed, by the time specified in Section 2.1 and (ii) in the case of any Letter of Credit, a Letter of Credit Application, duly executed and completed, by the time specified in Section 2.2.

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(b) Representations and Warranties. The representations and warranties made by the Borrower in any Credit Document are true and correct in all material respects at and as if made as of such date except to the extent they expressly and exclusively relate to an earlier date.

(c) No Default. No Default or Event of Default shall exist and be continuing either prior to or after giving effect to such Credit Extension.

(d) Availability. Immediately after giving effect to such Credit Extension (and the application of the proceeds thereof), (i) the aggregate principal amount of outstanding Revolving Loans plus the aggregate principal amount of outstanding L/C Obligations shall not exceed the Revolving Committed Amount, (ii) with respect to each individual Lender, the sum of outstanding principal amount of Revolving Loans of such Lender and outstanding principal amount of L/C Obligations of such Lender shall not exceed such Lender's Pro Rata Share of the Revolving Committed Amount and (iii) the aggregate amount of L/C Obligations shall not exceed the Letter of Credit Sublimit.

The delivery of each Notice of Borrowing or a Letter of Credit Application shall constitute a representation and warranty by the Borrower of the correctness of the matters specified in subsections (b), (c) and (d) above.

SECTION 6

REPRESENTATIONS AND WARRANTIES

To induce the Administrative Agent and the Lenders to enter into this Credit Agreement and to induce the Lenders to extend the credit contemplated hereby, the Borrower represents and warrants to the Administrative Agent and the Lenders as follows:

6.1 Organization and Good Standing.

Each of the Borrower and its Subsidiaries (a) is a corporation, duly organized, validly existing and in good standing under the laws of the jurisdiction of its organization, (b) is duly qualified and in good standing as a foreign entity authorized to do business in every other jurisdiction where the failure to so qualify would have a Material Adverse Effect and (c) has the requisite power and authority to own its properties and to carry on its business as now conducted and as proposed to be conducted.

6.2 Due Authorization.

The Borrower (a) has the requisite power and authority to execute, deliver and perform this Credit Agreement and the other Credit Documents and to incur the obligations herein and therein provided for and (b) has been authorized by all necessary action to execute, deliver and perform this Credit Agreement and the other Credit Documents.

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6.3 No Conflicts.

Neither the execution and delivery of this Credit Agreement and the other Credit Documents, nor the consummation of the transactions contemplated herein and therein, nor performance of and compliance with the terms and provisions hereof and thereof by the Borrower will (a) violate or conflict with any provision of its organizational documents, (b) violate, contravene or conflict with any law (including without limitation, the Public Utility Holding Company Act of 1935, as amended), regulation (including without limitation, Regulation U and Regulation X), order, writ, judgment, injunction, decree or permit applicable to it, (c) violate, contravene or conflict with contractual provisions of, or cause an event of default under, any indenture, loan agreement, mortgage, deed of trust, contract or other agreement or instrument to which it is a party or by which it may be bound, the violation of which would have or would be reasonably expected to have a Material Adverse Effect or (d) result in or require the creation of any Lien upon or with respect to its properties.

6.4 Consents.

Other than the filing of annual short-term financing plans with the New Mexico Public Regulation Commission in the normal course of business, no consent, approval, authorization or order of, or filing, registration or qualification with, any court or Governmental Authority or third party is required in connection with the execution, delivery or performance of this Credit Agreement or any of the other Credit Documents that has not been obtained or completed.

6.5 Enforceable Obligations.

This Credit Agreement and the other Credit Documents have been duly executed and delivered and constitute the legal, valid and binding obligations of the Borrower enforceable against the Borrower in accordance with their respective terms, except as may be limited by Debtor Relief Laws or similar laws affecting creditors' rights generally or by general equitable principles.

6.6 Financial Condition.

The financial statements delivered to the Lender pursuant to Section 4.1(d) and pursuant to Sections 7.1(a) and (b): (i) have been prepared in accordance with GAAP except that the quarterly financial statements are subject to year-end adjustments and have fewer footnotes than annual statements and (ii) present fairly the financial condition, results of operations and cash flows of the Borrower and its Subsidiaries as of such date and for such periods. No opinion provided with respect to the Borrower's financial statements pursuant to
Section 7.1 (or as to any prior annual financial statements) has been withdrawn.

6.7 No Material Change.

(a) Since December 31, 2001, there has been no development or event relating to or affecting the Borrower which would have or would reasonably be expected to have a Material Adverse Effect.

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(b) Since December 31, 2001, there has been no sale, transfer or other disposition by the Borrower of any material part of its business or property, and no purchase or other acquisition by the Borrower of any business or property (including the Capital Stock of any other Person) material in relation to the financial condition of the Borrower, in each case which is not (i) reflected in the most recent financial statements delivered to the Lender pursuant to Section 4.1(d) or 7.1 or in the notes thereto or (ii) otherwise permitted by the terms of this Credit Agreement and communicated to the Lender.

6.8 No Default.

Neither the Borrower nor any of its Subsidiaries is in default in any respect under any contract, lease, loan agreement, indenture, mortgage, security agreement or other agreement or obligation to which it is a party or by which any of its properties is bound which default would have or would reasonably be expected to have a Material Adverse Effect. No Default or Event of Default presently exists and is continuing.

6.9 Litigation.

There are no actions, suits, investigations or legal, equitable, arbitration or administrative proceedings, pending or, to the knowledge of the Borrower, threatened against the Borrower or any of its Subsidiaries which would have or would reasonably be expected to have a Material Adverse Effect.

6.10 Taxes.

Each of the Borrower and its Subsidiaries has filed, or caused to be filed, all material tax returns (federal, state, local and foreign) required to be filed and paid all amounts of taxes shown thereon to be due (including interest and penalties) and has paid all other taxes, fees, assessments and other governmental charges (including mortgage recording taxes, documentary stamp taxes and intangibles taxes) owing by it, except for such taxes which are not yet delinquent or that are being contested in good faith and by proper proceedings, and against which adequate reserves are being maintained in accordance with GAAP.

6.11 Compliance with Law.

Each of the Borrower and its Subsidiaries is in compliance with all laws, rules, regulations, orders and decrees applicable to it or to its properties, unless such failure to comply would not have or would not reasonably be expected to have a Material Adverse Effect.

6.12 ERISA.

Except as would not result or reasonably be expected to result in a Material Adverse Effect:

(a) During the five-year period prior to the date on which this representation is made or deemed made: (i) no ERISA Event has occurred, and, to the best knowledge of the Borrower, no event or condition has occurred or exists as a result of which any ERISA Event would be reasonably expected to occur, with respect to any Plan; (ii) no "accumulated funding deficiency," as such term is defined in Section

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302 of ERISA and Section 412 of the Code, whether or not waived, has occurred with respect to any Plan; (iii) each Plan has been maintained, operated, and funded in compliance with its own terms and in material compliance with the provisions of ERISA, the Code, and any other applicable federal or state laws; and (iv) no Lien in favor or the PBGC or a Plan has arisen or is reasonably likely to arise on account of any Plan.

(b) The actuarial present value of all "benefit liabilities" under each Single Employer Plan (determined within the meaning of
Section 401(a)(2) of the Code, utilizing the actuarial assumptions used to fund such Plans), whether or not vested, did not, as of the last annual valuation date prior to the date on which this representation is made or deemed made, exceed the current value of the assets of such Plan allocable to such accrued liabilities, except as disclosed in the Borrower's financial statements.

(c) Neither the Borrower nor any ERISA Affiliate has incurred, or, to the best knowledge of the Borrower, is reasonably expected to incur, any withdrawal liability under ERISA to any Multiemployer Plan or Multiple Employer Plan. Neither the Borrower nor any ERISA Affiliate has received any notification that any Multiemployer Plan is in reorganization (within the meaning of Section 4241 of ERISA), is insolvent (within the meaning of Section 4245 of ERISA), or has been terminated (within the meaning of Title IV of ERISA), and no Multiemployer Plan is, to the best knowledge of the Borrower, reasonably expected to be in reorganization, insolvent, or terminated.

(d) No prohibited transaction (within the meaning of Section 406 of ERISA or Section 4975 of the Code) or breach of fiduciary responsibility has occurred with respect to a Plan which has subjected or would be reasonably likely to subject the Borrower or any ERISA Affiliate to any liability under Sections 406, 409, 502(i), or 502(l) of ERISA or Section 4975 of the Code, or under any agreement or other instrument pursuant to which the Borrower or any ERISA Affiliate has agreed or is required to indemnify any person against any such liability.

(e) The present value (determined using actuarial and other assumptions which are reasonable with respect to the benefits provided and the employees participating) of the liability of the Borrower and each ERISA Affiliate for post-retirement welfare benefits to be provided to their current and former employees under Plans which are welfare benefit plans (as defined in Section 3(1) of ERISA), net of all assets under all such Plans allocable to such benefits, are reflected on the financial statements referenced in Section 7.1 in accordance with FASB 106.

(f) Each Plan which is a welfare plan (as defined in Section 3(1) of ERISA) to which Sections 601-609 of ERISA and Section 4980B of the Code apply has been administered in compliance in all material respects with such sections.

6.13 Use of Proceeds; Margin Stock.

The proceeds of the Credit Extensions hereunder will be used solely for the purposes specified in Section 7.9. None of such proceeds will be used for the purpose of (a) (i) purchasing or carrying any Margin Stock or (ii) reducing

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or retiring any Indebtedness which was originally incurred to purchase or carry Margin Stock, or (iii) for any other purpose that might constitute this transaction a "purpose credit" within the meaning of Regulation U or (b) for the acquisition of another Person unless the board of directors (or other comparable governing body) or stockholders, as appropriate, of such Person has approved such acquisition.

6.14 Government Regulation.

(a) The Borrower is not a "holding company" within the meaning of the Public Utility Holding Company Act of 1935, as amended ("PUHCA"). The issuance of the Note by the Borrower and the Credit Extensions contemplated by this Credit Agreement are not subject to regulation under PUHCA or subject to regulation by the Securities and Exchange Commission

(b) The Borrower is not an "investment company" registered or required to be registered under the Investment Company Act of 1940, as amended, or controlled by such a company.

6.15 Solvency.

The Borrower is and, after the consummation of the transactions contemplated by this Credit Agreement, will be Solvent.

6.16 Disclosure.

Neither this Credit Agreement nor any financial statements delivered to the Lender nor any other document, certificate or statement furnished to the Lender by or on behalf of the Borrower in connection with the transactions contemplated hereby contains any untrue statement of a material fact or omits to state a material fact necessary in order to make the statements contained therein or herein, taken as a whole, not misleading.

6.17 Environmental Matters.

Except as would not result or reasonably be expected to result in a Material Adverse Effect: (a) each of the properties of the Borrower and its Subsidiaries (the "Properties") and all operations at the Properties are in substantial compliance with all applicable Environmental Laws, (b) there is no undocumented or unreported violation of any Environmental Law with respect to the Properties or the businesses operated by the Borrower and its Subsidiaries (the "Businesses") that the Borrower is aware of, and (c) there are no conditions relating to the Businesses or Properties that have given rise to or would reasonably be expected to give rise to a liability under any applicable Environmental Laws.

6.18 Material Leases.

Set forth on Schedule 6.18 hereto is a complete and accurate list of the Material Leases on the date hereof, showing the expiration date and annual rental cost thereof. The Borrower is entitled to exercise all of the rights of lessee purported to be granted to the Borrower under each such Material Lease.

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6.19 Material Lease Interest Payments and Discount Rate.

Schedule 6.19 hereto, as most recently provided to the Administrative Agent, sets forth the same (a) amounts with respect to the interest portion of payments under the Material Leases and (b) discount rate used to calculate the net present value of all amounts payable under the Material Leases as have been most recently provided (or that the Borrower intends to provide shortly) to Moody's and S&P or as have otherwise been agreed to by the Required Lenders.

SECTION 7

AFFIRMATIVE COVENANTS

The Borrower covenants and agrees that, until the termination of the Commitments, the termination or expiration of all Letters of Credit and the payment in full of all Borrower Obligations:

7.1 Information Covenants.

The Borrower will furnish, or cause to be furnished, to the Lenders:

(a) Annual Financial Statements. As soon as available, and in any event within 120 days after the close of each fiscal year of the Borrower, a consolidated balance sheet and income statement of the Borrower and its Subsidiaries, as of the end of such fiscal year, together with the related consolidated statements of income and of cash flows for such fiscal year, setting forth in comparative form figures for the preceding fiscal year, all such financial information described above to be in reasonable form and detail and, in each case, audited by independent certified public accountants of recognized national standing reasonably acceptable to the Lender and whose opinion shall be furnished to the Lender, and shall be to the effect that such financial statements have been prepared in accordance with GAAP (except for changes with which such accountants concur) and shall not be limited as to the scope of the audit or qualified in any respect.

(b) Quarterly Financial Statements. As soon as available, and in any event within 60 days after the close of each fiscal quarter of the Borrower (other than the fourth fiscal quarter), a consolidated balance sheet and income statement of the Borrower and its Subsidiaries as of the end of such fiscal quarter, together with the related consolidated statement of income for such fiscal quarter and a year to date statement of cash flows, in each case setting forth in comparative form figures for the corresponding period of the preceding fiscal year, all such financial information described above to be in reasonable form and detail and reasonably acceptable to the Lender, and, in each case, accompanied by a certificate of a Financial Officer of the Borrower to the effect that such quarterly financial statements fairly present in all material respects the financial condition of such Person and have been prepared in accordance with GAAP, subject to changes resulting from audit and normal year-end audit adjustments and except that the quarterly financial statements have fewer footnotes than annual statements.

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(c) Officer's Certificate. At the time of delivery of the financial statements provided for in Sections 7.1(a) and 7.1(b) above, a certificate of a Financial Officer substantially in the form of Exhibit 7.1(c): (i) setting forth calculations demonstrating compliance by the Borrower with the financial covenants set forth in Section 7.2 as of the end of such fiscal period and (ii) stating that no Default or Event of Default exists, or if any Default or Event of Default does exist, specifying the nature and extent thereof and what action the Borrower proposes to take with respect thereto.

(d) Reports. Notice of the filing by the Borrower of any Form 10-Q, Form 10-K or Form 8-K with the SEC promptly upon the filing thereof and copies of all financial statements, proxy statements, notices and reports as the Borrower shall send to its shareholders concurrently with the mailing of any such statements, notices or reports to its shareholders.

(e) Notices. Upon the Borrower obtaining knowledge thereof, the Borrower will give written notice to the Lender within ten days of
(i) the occurrence of a Default or Event of Default, specifying the nature and extent thereof and what action the Borrower proposes to take with respect thereto and (ii) the occurrence of any of the following with respect to the Borrower or any of its Subsidiaries (A) the pendency or commencement of any litigation, arbitration or governmental proceeding against the Borrower or any of its Subsidiaries which, if adversely determined, would have or would reasonably be expected to have a Material Adverse Effect, (B) one or more judgments, orders, or decrees shall be entered against the Borrower or any of its Subsidiaries involving a liability of $5,000,000 or more, in the aggregate or (C) the institution of any proceedings against the Borrower or any of its Subsidiaries with respect to, or the receipt of notice by such Person of potential liability or responsibility for violation or alleged violation of, any federal, state or local law, rule or regulation (including, without limitation, any Environmental Law), the violation of which would have or would reasonably be expected to have a Material Adverse Effect.

(f) ERISA. Upon the Borrower or any ERISA Affiliate obtaining knowledge thereof, the Borrower will give written notice to the Lender promptly (and in any event within ten days) of any of the following which would result in or reasonably would be expected to result in a Material Adverse Effect: (i) any event or condition, including, but not limited to, any Reportable Event, that constitutes, or would be reasonably expected to lead to, an ERISA Event; (ii) with respect to any Multiemployer Plan, the receipt of notice as prescribed in ERISA or otherwise of any withdrawal liability assessed against the Borrower or any of its ERISA Affiliates, or of a determination that any Multiemployer Plan is in reorganization or insolvent (both within the meaning of Title IV of ERISA); (iii) the failure to make full payment on or before the due date (including extensions) thereof of all amounts which the Borrower or any of its Subsidiaries or ERISA Affiliates is required to contribute to each Plan pursuant to its terms and as required to meet the minimum funding standard set forth in ERISA and the Code with respect thereto; or (iv) a change in the funding status of any Plan, in each case together with a description of any such event or condition or a copy of any such notice and a statement by an officer of the Borrower briefly setting forth the details regarding such event,

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condition, or notice, and the action, if any, which has been or is being taken or is proposed to be taken with respect thereto. Promptly upon request, the Borrower shall furnish the Lender with such additional information concerning any Plan as may be reasonably requested, including, but not limited to, copies of each annual report/return (Form 5500 series), as well as all schedules and attachments thereto required to be filed with the Department of Labor and/or the Internal Revenue Service pursuant to ERISA and the Code, respectively, for each "plan year" (within the meaning of Section 3(39) of ERISA).

(g) Debt Ratings. Promptly upon any change in its Debt Ratings.

(h) Other Information. With reasonable promptness upon any such request, such other information regarding the business, properties or financial condition of the Borrower as the Lender may reasonably request.

7.2 Financial Covenants.

(a) Debt Capitalization. At all times the ratio of (i) Consolidated Indebtedness to (ii) Consolidated Capitalization shall be less than or equal to .65 to 1.0. For purposes of such calculation, the portion of Consolidated Indebtedness attributable to obligations under Material Leases shall be the net present value (using (i) the discount rate (A) set forth in Schedule 6.19, so long as Schedule 6.19 specifies the same relevant discount rate as is used in calculating such net present value provided to Moody's and S&P or (B) the discount rate used in calculating such net present value provided to Moody's and S&P or
(ii) any such other rate as shall be proposed by the Borrower (and agreed upon by the Required Lenders) of all amounts payable under the Material Leases.

(b) Interest Coverage Ratio. As of the last day of each fiscal quarter of the Borrower, for the twelve month period ending on such date, the ratio of (i) Consolidated EBITDA to (ii) Consolidated Interest Expense shall be greater than or equal to 3.0 to 1.0.

7.3 Preservation of Existence and Franchises.

(a) The Borrower will do (and will cause each of its Subsidiaries to do) all things necessary to preserve and keep in full force and effect its existence and rights, franchises and authority.

(b) The Borrower will maintain (and will cause each of its Subsidiaries to maintain) its properties in good condition and not waste or otherwise permit such properties to deteriorate, reasonable wear and tear excepted.

7.4 Books and Records.

The Borrower will keep (and will cause each of its Subsidiaries to keep) complete and accurate books and records of its transactions in accordance with good accounting practices on the basis of GAAP (including the establishment and maintenance of appropriate reserves).

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7.5 Compliance with Law.

(a) The Borrower will comply (and will cause each of its Subsidiaries to comply) with all laws (including, without limitation, all Environmental Laws and ERISA laws), rules, regulations and orders, and all applicable restrictions imposed by all Governmental Authorities, applicable to it and its properties, if the failure to comply would have or would reasonably be expected to have a Material Adverse Effect.

(b) The Borrower will timely file with the New Mexico Public Regulation Commission such short-term financing plans (and obtain all appropriate approvals) as are necessary to ensure that the indebtedness incurred hereunder is permitted.

7.6 Payment of Taxes and Other Indebtedness.

The Borrower will (and will cause each of its Subsidiaries to) pay, settle or discharge (a) all taxes, assessments and governmental charges or levies imposed upon it, or upon its income or profits, or upon any of its properties, before they shall become delinquent, (b) all lawful claims (including claims for labor, materials and supplies) which, if unpaid, might give rise to a Lien upon any of its properties, and (c) all of its other Indebtedness as it shall become due (to the extent such repayment is not otherwise prohibited by this Credit Agreement); provided, however, that the Borrower and its Subsidiaries shall not be required to pay any such tax, assessment, charge, levy, claim or Indebtedness which is being contested in good faith by appropriate proceedings and as to which adequate reserves therefor have been established in accordance with GAAP, unless the failure to make any such payment (i) would give rise to an immediate right to foreclose or collect on a Lien securing such amounts or (ii) would have or would be reasonably expected to have a Material Adverse Effect.

7.7 Insurance.

The Borrower will (and will cause each of its Subsidiaries to) at all times maintain in full force and effect insurance (including worker's compensation insurance and general liability insurance) in such amounts, covering such risks and liabilities and with such deductibles or self-insurance retentions as are in accordance with normal industry practice.

7.8 Performance of Obligations.

The Borrower will perform (and will cause each of its Subsidiaries to perform) in all material respects all of its obligations under the terms of all material agreements, indentures, mortgages, security agreements or other debt instruments to which it is a party or by which it is bound.

7.9 Use of Proceeds.

The proceeds of the Credit Extensions may be used solely (a) to repay amounts under the Existing Credit Agreement, (b) to pay fees and expenses required by the Credit Document, and (c) for general corporate purposes of the Borrower (including working capital and capital expenditures).

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7.10 Audits/Inspections.

Upon reasonable notice and during normal business hours, the Borrower will permit representatives appointed by the Lender, including, without limitation, independent accountants, agents, attorneys, and appraisers to visit and inspect the Borrower's property, including its books and records, its accounts receivable and inventory, the Borrower's facilities and its other business assets, and to make photocopies or photographs thereof and to write down and record any information such representative obtains and shall permit the Lender or its representatives to investigate and verify the accuracy of information provided to the Lender and to discuss all such matters with the officers, employees and representatives of the Borrower; provided, that an officer or authorized agent of the Borrower shall be present during any such discussions between the officers, employees or representatives of the Borrower and the representatives of the Lender.

SECTION 8

NEGATIVE COVENANTS

Unless otherwise approved in writing by the Required Lenders, the Borrower covenants and agrees that, until the termination of the Commitments, the termination or expiration of all Letters of Credit and the payment in full of all Borrower Obligations:

8.1 Nature of Business.

The Borrower will not materially alter the character of its business from that conducted as of the Closing Date.

8.2 Consolidation and Merger.

The Borrower will not (a) enter into any transaction of merger or (b) consolidate, liquidate, wind up or dissolve itself (or suffer any liquidation or dissolution); provided that, so long as no Default or Event of Default shall exist or be caused thereby, a Person may be merged or consolidated with or into the Borrower so long as the Borrower shall be the continuing or surviving corporation.

8.3 Sale or Lease of Assets.

The Borrower will not (nor will it permit its Subsidiaries to) sell, lease, transfer or otherwise dispose of, any of its assets (including, without limitation, all or substantially all of its assets, whether in one transaction or a series of related transactions) except (a) sales of accounts receivable and energy services contract revenues in connection with the 3838 Securitization and other sales of accounts receivable and energy services contract revenues so long as such other sales are non-recourse to the Borrower and are otherwise on customary market terms; (b) sales of assets (excluding those permitted in clause
(a) hereof) for fair value, if the aggregate value of all such transactions in any calendar year, does not exceed 25% of the book value of Total Assets, as calculated as of the end of the most recent fiscal quarter; and (c) sale, lease, transfer or other disposition, at less than fair value, of any other assets, provided that the aggregate book value of such assets shall not exceed $10,000,000 in any calendar year.

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8.4 Affiliate Transactions.

The Borrower will not enter into any transaction or series of transactions, whether or not in the ordinary course of business, with any Affiliate other than on terms and conditions substantially as favorable as would be obtainable in a comparable arm's-length transaction with a Person other than an Affiliate.

8.5 Liens.

The Borrower will not (and will not permit its Subsidiaries to) contract, create, incur, assume or permit to exist any Lien with respect to any of its property or assets of any kind (whether real or personal, tangible or intangible), whether now owned or hereafter acquired, securing any Indebtedness other than the following: (a) Liens securing Borrower Obligations, (b) Liens for taxes not yet due or Liens for taxes being contested in good faith by appropriate proceedings for which adequate reserves determined in accordance with GAAP have been established (and as to which the property subject to any such Lien is not yet subject to foreclosure, sale or loss on account thereof),
(c) Liens in respect of property imposed by law arising in the ordinary course of business such as materialmen's, mechanics', warehousemen's, carrier's, landlords' and other nonconsensual statutory Liens which are not yet due and payable, which have been in existence less than 90 days or which are being contested in good faith by appropriate proceedings for which adequate reserves determined in accordance with GAAP have been established (and as to which the property subject to any such Lien is not yet subject to foreclosure, sale or loss on account thereof), (d) pledges or deposits made in the ordinary course of business to secure payment of worker's compensation insurance, unemployment insurance, pensions or social security programs, (e) Liens arising from good faith deposits in connection with or to secure performance of tenders, bids, leases, government contracts, performance and return-of-money bonds and other similar obligations incurred in the ordinary course of business (other than obligations in respect of the payment of borrowed money), (f) Liens arising from good faith deposits in connection with or to secure performance of statutory obligations and surety and appeal bonds, (g) easements, rights-of-way, restrictions (including zoning restrictions), minor defects or irregularities in title and other similar charges or encumbrances not, in any material respect, impairing the use of the encumbered property for its intended purposes, (h) judgment Liens that would not constitute an Event of Default, (i) Liens arising by virtue of any statutory or common law provision relating to banker's liens, rights of setoff or similar rights as to deposit accounts or other funds maintained with a creditor depository institution, (j) any Lien created or arising over any property which is acquired, constructed or created by the Borrower or its Subsidiaries, but only if (i) such Lien secures only principal amounts (not exceeding the cost of such acquisition, construction or creation) raised for the purposes of such acquisition, construction or creation, together with any costs, expenses, interest and fees incurred in relation thereto or a guarantee given in respect thereof, (ii) such Lien is created or arises on or before 180 days after the completion of such acquisition, construction or creation, (iii) such Lien is confined solely to the property so acquired, constructed or created and any improvements thereto and (iv) the aggregate principal amount of all Indebtedness secured by such Liens shall not exceed $25,000,000 at any one time outstanding, (k) any Lien on Margin Stock, (l) the

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FMB Indenture, but only to the extent of the Insured Series First Mortgage Bonds, and the "permitted encumbrances" under the FMB Indenture, (m) the assignment of, or Liens on, accounts receivable in connection with 3838 Securitization and the filing of related financing statements under the Uniform Commercial Code of the applicable jurisdictions, (n) the assignment of, or Liens on, demand, energy or wheeling revenues, or on capacity reservation or option fees, payable to the Borrower with respect to any wholesale electric service or transmission agreements, the assignment of, or Liens on, revenues from energy services contracts, and the assignment of, or Liens on, capacity reservation or option fees payable to the Borrower with respect to asset sales permitted herein, (o) any extension, renewal or replacement (or successive extensions, renewals or replacements), as a whole or in part, of any Liens referred to in the foregoing clauses (a) through (n), for amounts not exceeding the principal amount of the Indebtedness secured by the Lien so extended, renewed or replaced, provided that such extension, renewal or replacement Lien is limited to all or a part of the same property or assets that were covered by the Lien extended, renewed or replaced (plus improvements on such property or assets), (p) Liens on Property that is subject to a Material Lease that is classified as an operating lease as of the Closing Date but which is subsequently converted into a capital lease, and (q) Liens on Property, in addition to those otherwise permitted by clauses (a) through (p) above, securing, directly or indirectly, Indebtedness or obligations arising pursuant to other agreements entered into in the ordinary course of business which do not exceed, in the aggregate at any one time outstanding, $25,000,000.

8.6 Accounting Changes.

The Borrower will not make or permit, or permit any of its Subsidiaries to make or permit, any change in accounting policies or reporting practices, except as required by GAAP, or as permitted by GAAP, if the amounts involved are not material.

SECTION 9

EVENTS OF DEFAULT

9.1 Events of Default.

An Event of Default shall exist upon the occurrence of any of the following specified events (each an "Event of Default"):

(a) Payment. The Borrower shall: (i) default in the payment when due of any principal of any of the Revolving Loans; or (ii) default, and such default shall continue for three or more Business Days, in the payment when due of any interest on the Loans or of any fees or other amounts owing hereunder, under any of the other Credit Documents or in connection herewith or therewith.

(b) Representations. Any representation, warranty or statement made or deemed to be made by the Borrower herein, in any of the other Credit Documents, or in any statement or certificate delivered or required to be delivered pursuant hereto or thereto shall prove untrue in any material respect on the date as of which it was deemed to have been made.

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(c) Covenants. The Borrower shall:

(i) default in the due performance or observance of any term, covenant or agreement contained in Sections 7.2,
7.3(a) (solely with respect to the existence of the Borrower), 7.9, 7.10 or 8.1 through 8.6, inclusive; or

(ii) default in the due performance or observance by it of any term, covenant or agreement (other than those referred to in subsections (a), (b) or (c)(i) of this Section 9.1) contained in this Credit Agreement or any other Credit Document and such default shall continue unremedied for a period of at least 10 days after the earlier of the Borrower becoming aware of such default or notice thereof given by the Lender.

(d) Credit Documents. Any Credit Document shall fail to be in force and effect or the Borrower shall so assert or any Credit Document shall fail to give the Lender the rights, powers, liens and privileges purported to be created thereby.

(e) Bankruptcy, etc. The occurrence of any of the following with respect to the Borrower or any of its Subsidiaries (i) a court or governmental agency having jurisdiction in the premises shall enter a decree or order for relief in respect of the Borrower or any of its Subsidiaries in an involuntary case under any applicable Debtor Relief Law now or hereafter in effect, or appoint a receiver, liquidator, assignee, custodian, trustee, sequestrator or similar official of the Borrower or any of its Subsidiaries or for any substantial part of their property or ordering the winding up or liquidation of its affairs; or (ii) an involuntary case under any applicable Debtor Relief Law now or hereafter in effect is commenced against the Borrower or any of its Subsidiaries and such petition remains unstayed and in effect for a period of 60 consecutive days; or (iii) the Borrower or any of its Subsidiaries shall commence a voluntary case under any applicable Debtor Relief Law now or hereafter in effect, or consent to the entry of an order for relief in an involuntary case under any such law, or consent to the appointment or taking possession by a receiver, liquidator, assignee, custodian, trustee, sequestrator or similar official of such Person or any substantial part of its property or make any general assignment for the benefit of creditors; or (iv) the Borrower or any of its Subsidiaries shall admit in writing its inability to pay its debts generally as they become due or any action shall be taken by any Person in furtherance of any of the aforesaid purposes.

(f) Defaults under Other Agreements.

(i) The Borrower or any of its Subsidiaries shall default in the due performance or observance (beyond the applicable grace period with respect thereto) of any material obligation or condition of any contract or lease to which it is a party, if such default would have or would reasonably be expected to have a Material Adverse Effect.

(ii) With respect to any Indebtedness of the Borrower or any of its Subsidiaries (other than Indebtedness outstanding under this Credit Agreement) in excess of $20,000,000 in the aggregate (A) the Borrower or such Subsidiary shall (x) default in any payment (beyond the applicable grace period with respect thereto, if any) with

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respect to such Indebtedness, or (y) default (after giving effect to any applicable grace period) in the observance or performance of any covenant or agreement relating to such Indebtedness or contained in any instrument or agreement evidencing, securing or relating thereto, or any other event or condition shall occur or condition exist, the effect of which default or other event or condition is to cause or permit the holder or the holders of such Indebtedness (or any trustee or agent on behalf of such holders) to cause (determined without regard to whether any notice or lapse of time is required) such Indebtedness to become due prior to its stated maturity; or (B) such Indebtedness shall be declared due and payable, or required to be prepaid other than by a regularly scheduled required prepayment prior to the stated maturity thereof; or (C) such Indebtedness shall mature and remain unpaid.

(g) Judgments. Any judgment, order or decree involving a liability of $20,000,000 or more, or one or more judgments, orders, or decrees involving a liability of $40,000,000 or more, in the aggregate, shall be entered against the Borrower or any of its Subsidiaries and such judgments, orders or decrees shall continue unsatisfied, undischarged and unstayed for a period ending on the first to occur of
(i) the last day on which such judgment, order or decree becomes final and unappealable and, where applicable, with the status of a judicial lien or (ii) 60 days; provided that if such judgment, order or decree provides for periodic payments over time then the Borrower or such Subsidiary shall have a grace period of 30 days with respect to each such periodic payment.

(h) ERISA. The occurrence of any of the following events or conditions if any of the same would have or would be reasonably expected to have a Material Adverse Effect: (i) any "accumulated funding deficiency," as such term is defined in Section 302 of ERISA and Section 412 of the Code, whether or not waived, shall exist with respect to any Plan, or any lien shall arise on the assets of the Borrower or any ERISA Affiliate in favor of the PBGC or a Plan; (ii) an ERISA Event shall occur with respect to a Single Employer Plan which is, in the reasonable opinion of the Lender, likely to result in the termination of such Plan for purposes of Title IV of ERISA; (iii) an ERISA Event shall occur with respect to a Multiemployer Plan or Multiple Employer Plan which is, in the reasonable opinion of the Lender, likely to result in (A) the termination of such Plan for purposes of Title IV of ERISA, or (B) the Borrower or any ERISA Affiliate incurring any liability in connection with a withdrawal from, reorganization of (within the meaning of Section 4241 of ERISA), or insolvency (within the meaning of Section 4245 of ERISA) of such Plan; or (iv) any prohibited transaction (within the meaning of Section 406 of ERISA or Section 4975 of the Code) or breach of fiduciary responsibility shall occur which would be reasonably expected to subject the Borrower or any ERISA Affiliate to any liability under Sections 406, 409, 502(i), or 502(l) of ERISA or Section 4975 of the Code, or under any agreement or other instrument pursuant to which the Borrower or any ERISA Affiliate has agreed or is required to indemnify any person against any such liability.

(i) Change of Control. There shall occur a Change of Control.

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9.2 Acceleration; Remedies.

Upon the occurrence and during the continuation of an Event of Default, the Administrative Agent may or, upon the request and direction of the Required Lenders, shall take the following actions without prejudice to the rights of the Administrative Agent or any Lender to enforce its claims against the Borrower, except as otherwise specifically provided for herein:

(a) Termination of Commitments. Declare the Commitments and the obligation of the L/C Issuer to make L/C Credit Extensions terminated whereupon the Commitments and the obligation of the L/C Issuer to make L/C Credit Extensions shall be immediately terminated.

(b) Acceleration of Revolving Loans. Declare the unpaid principal of and any accrued interest in respect of all Revolving Loans, all L/C Obligations and any and all other Borrower Obligations of any and every kind owing by the Borrower to the Administrative Agent or the Lenders under the Credit Documents to be due, whereupon the same shall be immediately due and payable without presentment, demand, protest or other notice of any kind, all of which are hereby waived by the Borrower.

(c) Cash Collateral. Direct the Borrower to Cash Collateralize (and the Borrower agrees that upon receipt of such notice, or upon the occurrence of an Event of Default under Section 9.1(e), it will immediately Cash Collateralize) L/C Obligations in respect of subsequent drawings under all then outstanding Letters of Credit in an amount equal to the then outstanding principal amount of L/C Obligations.

(d) Enforcement of Rights. To the extent permitted by Law enforce any and all rights and interests created and existing under applicable Law and under the Credit Documents, including, without limitation, all rights of set-off.

Notwithstanding the foregoing, if an Event of Default specified in Section 9.1(e) shall occur, then the Commitments and any obligation of the L/C Issuer to make L/C Credit Extensions shall automatically terminate and all Revolving Loans, all L/C Obligations, all accrued interest in respect thereof, all accrued and unpaid fees and other Borrower Obligations owing to the Administrative Agent and the Lenders hereunder shall immediately become due and payable without the giving of any notice or other action by the Administrative Agent or the Lenders, which notice or other action is expressly waived by the Borrower.

Notwithstanding the fact that enforcement powers reside primarily with the Administrative Agent, each Lender has, to the extent permitted by Law, a separate right of payment and shall be considered a separate "creditor" holding a separate "claim" within the meaning of Section 101(5) of the Bankruptcy Code or any other insolvency statute.

9.3 Allocation of Payments After Event of Default.

Notwithstanding any other provisions of this Credit Agreement, after the occurrence and during the continuation of an Event of Default, all amounts collected or received by the Administrative Agent or any Lender on account of amounts outstanding under any of the Credit Documents shall be paid over or delivered as follows:

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FIRST, to the payment of all reasonable out-of-pocket costs and expenses (including the reasonable fees and expenses of legal counsel) of the Administrative Agent, the L/C Issuer or any of the Lenders in connection with enforcing the rights of the Administrative Agent, the L/C Issuer and the Lenders under the Credit Documents, ratably among them in proportion to the amounts described in this clause "FIRST" payable to them;

SECOND, to payment of any fees owed to the Administrative Agent, the L/C Issuer or any Lender, ratably among them in proportion to the amounts described in this clause "SECOND" payable to them;

THIRD, to the payment of all accrued interest payable to the Lenders, and the L/C Issuer hereunder, ratably among them in proportion to the amounts described in this clause "THIRD" payable to them;

FOURTH, to the payment of the outstanding principal amount of the Revolving Loans and L/C Obligations, ratably among them in proportion to the amounts described in this clause "FOURTH" payable to them;

FIFTH, to the Administrative Agent, for the account of the L/C Issuer, to Cash Collateralize that portion of the L/C Obligations comprised of the aggregate undrawn amount of Letters of Credit;

SIXTH, to all other Borrower Obligations which shall have become due and payable under the Credit Documents and not repaid pursuant to clauses "FIRST" through "FIFTH" above, ratably among the holders of such Borrower Obligations in proportion to the amounts described in this clause "SIXTH" payable to them; and

SEVENTH, the payment of the surplus, if any, to whomever may be lawfully entitled to receive such surplus.

Amounts used to Cash Collateralize the aggregate undrawn amount of Letters of Credit pursuant to clause "FIFTH" above shall be applied to satisfy drawings under such Letters of Credit as they occur. If any amount remains on deposit as cash collateral after all Letters of Credit have either been fully drawn or expired, such remaining amount shall be applied to the other Borrower Obligations, if any, in the order set forth above.

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SECTION 10

AGENCY PROVISIONS

10.1 Appointment and Authorization of Administrative Agent.

(a) Each Lender hereby irrevocably appoints, designates and authorizes the Administrative Agent to take such action on its behalf under the provisions of this Credit Agreement and each other Credit Document and to exercise such powers and perform such duties as are expressly delegated to it by the terms of this Credit Agreement or any other Credit Document, together with such powers as are reasonably incidental thereto. Notwithstanding any provision to the contrary contained elsewhere herein or in any other Credit Document, the Administrative Agent shall not have any duties or responsibilities, except those expressly set forth herein, nor shall the Administrative Agent have or be deemed to have any fiduciary relationship with any Lender or participant, and no implied covenants, functions, responsibilities, duties, obligations or liabilities shall be read into this Credit Agreement or any other Credit Document or otherwise exist against the Administrative Agent. Without limiting the generality of the foregoing sentence, the use of the term "agent" herein and in the other Credit Documents with reference to the Administrative Agent is not intended to connote any fiduciary or other implied (or express) obligations arising under agency doctrine of any applicable Requirement of Law. Instead, such term is used merely as a matter of market custom, and is intended to create or reflect only an administrative relationship between independent contracting parties.

(b) The L/C Issuer shall act on behalf of the Lenders with respect to any Letters of Credit issued by it and the documents associated therewith, and the L/C Issuer shall have all of the benefits and immunities (i) provided to the Administrative Agent in this Section 10 with respect to any acts taken or omissions suffered by the L/C Issuer in connection with Letters of Credit issued by it or proposed to be issued by it and the applications and agreements for letters of credit pertaining to such Letters of Credit as fully as if the term "Administrative Agent" as used in this Section 10 and in the definition of "Agent-Related Person" included the L/C Issuer with respect to such acts or omissions, and (ii) as additionally provided herein with respect to the L/C Issuer.

10.2 Delegation of Duties.

The Administrative Agent may execute any of its duties under this Credit Agreement or any other Credit Document by or through agents, employees or attorneys-in-fact and shall be entitled to advice of counsel and other consultants or experts concerning all matters pertaining to such duties. The Administrative Agent shall not be responsible for the negligence or misconduct of any agent or attorney-in-fact that it selects in the absence of gross negligence or willful misconduct.

10.3 Liability of Administrative Agent.

No Agent-Related Person shall (a) be liable for any action taken or omitted to be taken by any of them under or in connection with this Credit Agreement or any other Credit Document or the transactions contemplated hereby (except for its own gross negligence or willful misconduct in connection with its duties expressly set forth herein), or (b) be responsible in any manner to any Lender or participant for any recital, statement, representation or warranty

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made by the Borrower or any officer thereof, contained herein or in any other Credit Document, or in any certificate, report, statement or other document referred to or provided for in, or received by the Administrative Agent under or in connection with, this Credit Agreement or any other Credit Document, or the validity, effectiveness, genuineness, enforceability or sufficiency of this Credit Agreement or any other Credit Document, or for any failure of the Borrower or any other party to any Credit Document to perform its obligations hereunder or thereunder. No Agent-Related Person shall be under any obligation to any Lender or participant to ascertain or to inquire as to the observance or performance of any of the agreements contained in, or conditions of, this Credit Agreement or any other Credit Document, or to inspect the properties, books or records of the Borrower or any Affiliate thereof.

10.4 Reliance by Administrative Agent.

(a) The Administrative Agent shall be entitled to rely, and shall be fully protected in relying, upon any writing, communication, signature, resolution, representation, notice, consent, certificate, affidavit, letter, telegram, facsimile, telex or telephone message, electronic mail message, statement or other document or conversation believed by it to be genuine and correct and to have been signed, sent or made by the proper Person or Persons, and upon advice and statements of legal counsel (including counsel to the Borrower), independent accountants and other experts selected by the Administrative Agent. The Administrative Agent shall be fully justified in failing or refusing to take any action under any Credit Document unless it shall first receive such advice or concurrence of the Required Lenders as it deems appropriate and, if it so requests, it shall first be indemnified to its satisfaction by the Lenders against any and all liability and expense which may be incurred by it by reason of taking or continuing to take any such action. The Administrative Agent shall in all cases be fully protected in acting, or in refraining from acting, under this Credit Agreement or any other Credit Document in accordance with a request or consent of the Required Lenders (or such greater number of Lenders as may be expressly required hereby in any instance) and such request and any action taken or failure to act pursuant thereto shall be binding upon all the Lenders.

(b) For purposes of determining compliance with the conditions specified in Section 4.1, each Lender that has signed this Credit Agreement shall be deemed to have consented to, approved or accepted or to be satisfied with, each document or other matter required thereunder to be consented to or approved by or acceptable or satisfactory to a Lender unless the Administrative Agent shall have received notice from such Lender prior to the proposed Closing Date specifying its objection thereto.

10.5 Notice of Default.

The Administrative Agent shall not be deemed to have knowledge or notice of the occurrence of any Default or Event of Default, except with respect to defaults in the payment of principal, interest and fees required to be paid to the Administrative Agent for the account of the Lenders, unless the Administrative Agent shall have received written notice from a Lender or the Borrower referring to this Credit Agreement, describing such Default or Event of

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Default and stating that such notice is a "notice of default." The Administrative Agent will notify the Lenders of its receipt of any such notice. The Administrative Agent shall take such action with respect to such Default or Event of Default as may be directed by the Required Lenders in accordance with
Section 9; provided, however, that unless and until the Administrative Agent has received any such direction, the Administrative Agent may (but shall not be obligated to) take such action, or refrain from taking such action, with respect to such Default or Event of Default as it shall deem advisable or in the best interest of the Lenders.

10.6 Credit Decision; Disclosure of Information by the

Administrative Agent.

Each Lender acknowledges that no Agent-Related Person has made any representation or warranty to it, and that no act by the Administrative Agent hereafter taken, including any consent to and acceptance of any assignment or review of the affairs of the Borrower or any Affiliate thereof, shall be deemed to constitute any representation or warranty by any Agent-Related Person to any Lender as to any matter, including whether Agent-Related Persons have disclosed material information in their possession. Each Lender represents to the Administrative Agent that it has, independently and without reliance upon any Agent-Related Person and based on such documents and information as it has deemed appropriate, made its own appraisal of and investigation into the business, prospects, operations, property, financial and other condition and creditworthiness of the Borrower and their respective Subsidiaries, and all applicable bank or other regulatory Requirement of Laws relating to the transactions contemplated hereby, and made its own decision to enter into this Credit Agreement and to extend credit to the Borrower hereunder. Each Lender also represents that it will, independently and without reliance upon any Agent-Related Person and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit analysis, appraisals and decisions in taking or not taking action under this Credit Agreement and the other Credit Documents, and to make such investigations as it deems necessary to inform itself as to the business, prospects, operations, property, financial and other condition and creditworthiness of the Borrower. Except for notices, reports and other documents expressly required to be furnished to the Lenders by the Administrative Agent herein, the Administrative Agent shall not have any duty or responsibility to provide any Lender with any credit or other information concerning the business, prospects, operations, property, financial and other condition or creditworthiness of the Borrower or any of their respective Affiliates which may come into the possession of any Agent-Related Person.

10.7 Indemnification of Administrative Agent.

Whether or not the transactions contemplated hereby are consummated, the Lenders shall indemnify upon demand each Agent-Related Person (to the extent not reimbursed by or on behalf of the Borrower and without limiting the obligation of the Borrower to do so), pro rata, and hold harmless each Agent-Related Person from and against any and all Indemnified Liabilities incurred by it; provided, however, that no Lender shall be liable for the payment to any Agent-Related Person of any portion of such Indemnified Liabilities to the extent determined in a final, nonappealable judgment by a court of competent jurisdiction to have resulted from such Agent-Related Person's own gross negligence or willful misconduct; it being understood and agreed that no action taken in accordance with the directions of the Required Lenders shall be deemed to constitute gross negligence or willful misconduct for purposes of this Section. Without limitation of the foregoing, each Lender shall

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reimburse the Administrative Agent upon demand for its ratable share of any costs or out-of-pocket expenses (including, without limitation, the reasonable fees and expenses of legal counsel) incurred by the Administrative Agent in connection with the preparation, execution, delivery, administration, modification, amendment or enforcement (whether through negotiations, legal proceedings or otherwise) of, or legal advice in respect of rights or responsibilities under, this Credit Agreement, any other Credit Document, or any document contemplated by or referred to herein, to the extent that the Administrative Agent is not reimbursed for such expenses by or on behalf of the Borrower. The undertaking in this Section shall survive termination of the Commitments, the payment of all Borrower Obligations and the resignation of the Administrative Agent.

10.8 Administrative Agent in its Individual Capacity.

Bank of America and its Affiliates may make loans to, issue letters of credit for the account of, accept deposits from, acquire equity interests in and generally engage in any kind of banking, trust, financial advisory, underwriting or other business with the Borrower and its Affiliates as though Bank of America were not the Administrative Agent or the L/C Issuer hereunder and without notice to or consent of the Lenders. The Lenders acknowledge that, pursuant to such activities, Bank of America or its Affiliates may receive information regarding the Borrower or its Affiliates (including information that may be subject to confidentiality obligations in favor of the Borrower or an Affiliate) and acknowledge that the Administrative Agent shall be under no obligation to provide such information to them. With respect to its Revolving Loans, Bank of America shall have the same rights and powers under this Credit Agreement as any other Lender and may exercise such rights and powers as though it were not the Administrative Agent or the L/C Issuer, and the terms "Lender" and "Lenders" include Bank of America in its individual capacity. The foregoing provisions of this Section 10.8 shall apply equally to Lenders and their Affiliates to the extent such Lenders are acting in their individual capacities and not in their capacities as Lenders hereunder.

10.9 Successor Administrative Agent.

The Administrative Agent may resign as Administrative Agent upon 30 days' notice to the Lenders; provided that any such resignation by Bank of America shall also constitute its resignation as L/C Issuer. If the Administrative Agent resigns under this Credit Agreement, the Required Lenders shall appoint from among the Lenders a successor Administrative Agent for the Lenders, which successor Administrative Agent shall be consented to by the Borrower at all times other than during the existence of an Event of Default (which consent of the Borrower shall not be unreasonably withheld or delayed). If no successor Administrative Agent is appointed prior to the effective date of the resignation of the retiring Administrative Agent, the retiring Administrative Agent may appoint, after consulting with the Lenders and the Borrower, a successor Administrative Agent from among the Lenders. Upon the acceptance of its appointment as successor Administrative Agent hereunder, the Person acting as such successor Administrative Agent shall succeed to all the rights, powers and duties of the retiring Administrative Agent and the retiring L/C Issuer and the respective terms "Administrative Agent" and "L/C Issuer" shall mean such successor Administrative Agent and L/C Issuer and the retiring Administrative Agent's appointment, powers and duties as Administrative Agent shall be terminated and the retiring L/C Issuer's rights, powers and duties as such shall be terminated, without any other or further act or deed on the part

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of such retiring Administrative Agent or L/C Issuer or any other Lender, other than the obligation of the successor L/C Issuer to issue letters of credit in substitution for the Letters of Credit, if any, outstanding at the time of such succession or to make other arrangements satisfactory to the retiring L/C Issuer to effectively assume the obligations of the retiring L/C Issuer with respect to such Letters of Credit. After any retiring Administrative Agent's resignation hereunder as Administrative Agent, the provisions of this Section 10 and Sections 11.5 and 11.6 shall inure to its benefit as to any actions taken or omitted to be taken by it while it was Administrative Agent under this Credit Agreement. If no successor Administrative Agent has accepted appointment as Administrative Agent by the date which is 30 days following a retiring Administrative Agent's notice of resignation, the retiring Administrative Agent's resignation shall nevertheless thereupon become effective and the Lenders shall perform all of the duties of the Administrative Agent hereunder until such time, if any, as the Required Lenders appoint a successor Administrative Agent as provided for above.

10.10 Administrative Agent May File Proofs of Claim.

In case of the pendency of any receivership, insolvency, liquidation, bankruptcy, reorganization, arrangement, adjustment, composition or other judicial proceeding relative to the Borrower, the Administrative Agent (irrespective of whether the principal of any Revolving Loan or L/C Obligation shall then be due and payable as herein expressed or by declaration or otherwise and irrespective of whether the Administrative Agent shall have made any demand on the Borrower) shall be entitled and empowered, by intervention in such proceeding or otherwise

(a) to file and prove a claim for the whole amount of the principal and interest owing and unpaid in respect of the Revolving Loans, L/C Obligations and all other Borrower Obligations that are owing and unpaid and to file such other documents as may be necessary or advisable in order to have the claims of the Lenders and the Administrative Agent (including any claim for the reasonable compensation, expenses, disbursements and advances of the Lenders and the Administrative Agent and its respective agents and counsel and all other amounts due the Lenders and the Administrative Agent under Sections 3.4 and 11.5) allowed in such judicial proceeding; and

(b) to collect and receive any monies or other property payable or deliverable on any such claims and to distribute the same;

and any custodian, receiver, assignee, trustee, liquidator, sequestrator or other similar official in any such judicial proceeding is hereby authorized by each Lender to make such payments to the Administrative Agent and, in the event that the Administrative Agent shall consent to the making of such payments directly to the Lenders, to pay to the Administrative Agent any amount due for the reasonable compensation, expenses, disbursements and advances of the Administrative Agent and its agents and counsel, and any other amounts due the Administrative Agent under Sections 3.4 and 11.5.

Nothing contained herein shall be deemed to authorize the Administrative Agent to authorize or consent to or accept or adopt on behalf of any Lender any plan of reorganization, arrangement, adjustment or composition affecting the Borrower Obligations or the rights of any Lender or to authorize the Administrative Agent to vote in respect of the claim of any Lender in any such proceeding.

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10.11 Other Agents; Arrangers and Managers.

None of the Lenders or other Persons identified on the facing page or signature pages of this Credit Agreement as a "syndication agent," "documentation agent," "co-agent," "book manager," "lead manager," "arranger," "lead arranger" or "co-arranger" shall have any right, power, obligation, liability, responsibility or duty under this Credit Agreement other than, in the case of such Lenders, those applicable to all Lenders as such. Without limiting the foregoing, none of the Lenders or other Persons so identified shall have or be deemed to have any fiduciary relationship with any Lender. Each Lender acknowledges that it has not relied, and will not rely, on any of the Lenders or other Persons so identified in deciding to enter into this Credit Agreement or in taking or not taking action hereunder.

SECTION 11

MISCELLANEOUS

11.1 Notices and Other Communications; Facsimile Copies.

(a) General. Unless otherwise expressly provided herein, all notices and other communications provided for hereunder shall be in writing (including by facsimile transmission). All such written notices shall be mailed, faxed or delivered to the applicable address, facsimile number or (subject to subsection (c) below) electronic mail address, and all notices and other communications expressly permitted hereunder to be given by telephone shall be made to the applicable telephone number, as follows:

(i) if to the Borrower, the Administrative Agent or the L/C Issuer, to the address, facsimile number, electronic mail address or telephone number specified for such Person on Schedule 11.1 or to such other address, facsimile number, electronic mail address or telephone number as shall be designated by such party in a notice to the other parties; and

(ii) if to any other Lender, to the address, facsimile number, electronic mail address or telephone number specified in its Administrative Questionnaire or to such other address, facsimile number, electronic mail address or telephone number as shall be designated by such party in a notice to the Borrower, the Administrative Agent and the L/C Issuer.

All such notices and other communications shall be deemed to be given or made upon the earlier to occur of (i) actual receipt by the relevant party hereto and
(ii) (A) if delivered by hand or by courier, when signed for by or on behalf of the relevant party hereto; (B) if delivered by mail, four Business Days after deposit in the mails, postage prepaid; (C) if delivered by facsimile, when sent and receipt has been confirmed by telephone; and (D) if delivered by electronic

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mail (which form of delivery is subject to the provisions of subsection (c) below), when delivered; provided, however, that notices and other communications to the Administrative Agent and the L/C Issuer pursuant to Section 2 shall not be effective until actually received by such Person. In no event shall a voicemail message be effective as a notice, communication or confirmation hereunder.

(b) Effectiveness of Facsimile Documents and Signatures. Credit Documents may be transmitted and/or signed by facsimile. The effectiveness of any such documents and signatures shall, subject to applicable Requirement of Law, have the same force and effect as manually-signed originals and shall be binding on the Borrower, the Administrative Agent and the Lenders. The Administrative Agent may also require that any such documents and signatures be confirmed by a manually-signed original thereof; provided, however, that the failure to request or deliver the same shall not limit the effectiveness of any facsimile document or signature.

(c) Limited Use of Electronic Mail. Electronic mail and Internet and intranet websites may be used only to distribute routine communications, such as financial statements and other information as provided in Section 7.1 and 7.2, and to distribute Credit Documents for execution by the parties thereto, and may not be used for any other purpose.

(d) Reliance by Administrative Agent and Lenders. The Administrative Agent and the Lenders shall be entitled to rely and act upon any notices (including telephonic Notices of Borrowing) purportedly given by or on behalf of the Borrower even if (i) such notices were not made in a manner specified herein, were incomplete or were not preceded or followed by any other form of notice specified herein, or (ii) the terms thereof, as understood by the recipient, varied from any confirmation thereof. The Borrower shall indemnify each Agent-Related Person and each Lender from all losses, costs, expenses and liabilities resulting from the reliance by such Person on each notice purportedly given by or on behalf of the Borrower. All telephonic notices to and other communications with the Administrative Agent may be recorded by the Administrative Agent, and each of the parties hereto hereby consents to such recording.

11.2 Right of Set-Off.

In addition to any rights now or hereafter granted under applicable Law or otherwise, and not by way of limitation of any such rights, upon the occurrence of an Event of Default and the commencement of remedies described in
Section 9.2, each Lender is authorized at any time and from time to time, without presentment, demand, protest or other notice of any kind (all of which rights being hereby expressly waived), to set-off and to appropriate and apply any and all deposits (general or special) and any other indebtedness at any time held or owing by such Lender (including, without limitation, branches, agencies or Affiliates of such Lender wherever located) to or for the credit or the account of the Borrower against obligations and liabilities of the Borrower to the Lenders hereunder, under the Revolving Notes, the other Credit Documents or otherwise, irrespective of whether the Administrative Agent or the Lenders shall have made any demand hereunder and although such obligations, liabilities or claims, or any of them, may be contingent or unmatured, and any such set-off shall be deemed to have been made immediately upon the occurrence of an Event of Default even though such charge is made or entered on the books of such Lender subsequent thereto. The Borrower hereby agrees that any Person purchasing a participation in the Revolving Loans and Commitments hereunder pursuant to Sections 3.8 or 11.3(e) may exercise all rights of set-off with respect to its participation interest as fully as if such Person were a Lender hereunder.

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11.3 Successors and Assigns.

(a) The provisions of this Credit Agreement shall be binding upon and inure to the benefit of the parties hereto and their respective successors and assigns permitted hereby, except that the Borrower may not assign or otherwise transfer any of its rights or obligations hereunder without the prior written consent of each Lender and no Lender may assign or otherwise transfer any of its rights or obligations hereunder except (i) to an Eligible Assignee in accordance with the provisions of subsection (b) of this Section, (ii) by way of participation in accordance with the provisions of subsection (d) of this Section, or (iii) by way of pledge or assignment of a security interest subject to the restrictions of subsection (f) or (i) of this Section, or (iv) to an SPC in accordance with the provisions of subsection (g) of this Section (and any other attempted assignment or transfer by any party hereto shall be null and void). Nothing in this Credit Agreement, expressed or implied, shall be construed to confer upon any Person (other than the parties hereto, their respective successors and assigns permitted hereby, Participants to the extent provided in subsection (d) of this Section and, to the extent expressly contemplated hereby, the Indemnitees) any legal or equitable right, remedy or claim under or by reason of this Credit Agreement.

(b) Any Lender may at any time assign to one or more Eligible Assignees all or a portion of its rights and obligations under this Credit Agreement (including all or a portion of its Commitment and the Loans (including for purposes of this subsection (b), participations in L/C Obligations) at the time owing to it); provided that (i) except in the case of an assignment of the entire remaining amount of the assigning Lender's Commitment and the Loans at the time owing to it or in the case of an assignment to a Lender or an Affiliate of a Lender or an Approved Fund (as defined in subsection (g) of this Section) with respect to a Lender, the aggregate amount of the Commitment (which for this purpose includes Loans outstanding thereunder) subject to each such assignment, determined as of the date the Assignment and Assumption with respect to such assignment is delivered to the Administrative Agent or, if "Trade Date" is specified in the Assignment and Assumption, as of the Trade Date, shall not be less than $5,000,000 unless each of the Administrative Agent and, so long as no Event of Default has occurred and is continuing, the Borrower otherwise consents
(each such consent not to be unreasonably withheld or delayed); (ii) each partial assignment shall be made as an assignment of a proportionate part of all the assigning Lender's rights and obligations under this Credit Agreement with respect to the Loans or the Commitment assigned, (iii) any assignment of a Commitment must be approved by the Administrative Agent and the L/C Issuer (such approval not to be unreasonably withheld or delayed) unless the Person that is the proposed assignee is itself a Lender (whether or not the proposed assignee would otherwise qualify as an Eligible Assignee); and (iv) the parties to each assignment shall execute and deliver to the Administrative Agent an Assignment and Assumption, together with a processing and recordation fee of $3,500. Subject to acceptance and recording thereof by the Administrative Agent pursuant to subsection
(c) of this Section, from and after the effective date specified in each Assignment and Assumption, the Eligible Assignee thereunder shall

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be a party to this Credit Agreement and, to the extent of the interest assigned by such Assignment and Assumption, have the rights and obligations of a Lender under this Credit Agreement, and the assigning Lender thereunder shall, to the extent of the interest assigned by such Assignment and Assumption, be released from its obligations under this Credit Agreement (and, in the case of an Assignment and Assumption covering all of the assigning Lender's rights and obligations under this Credit Agreement, such Lender shall cease to be a party hereto but shall continue to be entitled to the benefits of Sections 3.9, 3.12, 3.13, 3.14, and 11.5(b) with respect to facts and circumstances occurring prior to the effective date of such assignment). Upon request, the Borrower (at its expense) shall execute and deliver a Note to the assignee Lender. Any assignment or transfer by a Lender of rights or obligations under this Credit Agreement that does not comply with this subsection shall be treated for purposes of this Credit Agreement as a sale by such Lender of a participation in such rights and obligations in accordance with subsection (d) of this Section.

(c) The Administrative Agent, acting solely for this purpose as an agent of the Borrower, shall maintain at the Administrative Agent's Office a copy of each Assignment and Assumption delivered to it and a register for the recordation of the names and addresses of the Lenders, and the Commitments of, and principal amounts of the Loans and L/C Obligations owing to, each Lender pursuant to the terms hereof from time to time (the "Register"). The entries in the Register shall be conclusive, and the Borrower, the Administrative Agent and the Lenders may treat each Person whose name is recorded in the Register pursuant to the terms hereof as a Lender hereunder for all purposes of this Credit Agreement, notwithstanding notice to the contrary. The Register shall be available for inspection by the Borrower and any Lender, at any reasonable time and from time to time upon reasonable prior notice.

(d) Any Lender may at any time, without the consent of, or notice to, the Borrower or the Administrative Agent, sell participations to any Person (other than a natural person or the Borrower or any of the Borrower's Affiliates or Subsidiaries) (each, a "Participant") in all or a portion of such Lender's rights and/or obligations under this Credit Agreement (including all or a portion of its Commitment and/or the Loans (including such Lender's participations in L/C Obligations) owing to it); provided that (i) such Lender's obligations under this Credit Agreement shall remain unchanged, (ii) such Lender shall remain solely responsible to the other parties hereto for the performance of such obligations and (iii) the Borrower, the Administrative Agent and the other Lenders shall continue to deal solely and directly with such Lender in connection with such Lender's rights and obligations under this Credit Agreement. Any agreement or instrument pursuant to which a Lender sells such a participation shall provide that such Lender shall retain the sole right to enforce this Credit Agreement and to approve any amendment, modification or waiver of any provision of this Credit Agreement; provided that such agreement or instrument may provide that such Lender will not, without the consent of the Participant, agree to any amendment, waiver or other modification described in the first proviso to Section 11.6 that directly affects such Participant. Subject to subsection (e) of this Section, the Borrower agrees that each Participant shall be entitled to the benefits of Sections 3.9, 3.12, 3.13 and 3.14 to the same extent as if it were a Lender and had acquired its interest by assignment pursuant to subsection (b) of this Section. To the extent permitted by Law, each Participant also shall be entitled to the benefits of Section 3.7 as though it were a Lender, provided such Participant agrees to be subject to Section 3.8 as though it were a Lender.

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(e) A Participant shall not be entitled to receive any greater payment under Section 3.9, 3.12, 3.13 or 3.14 than the applicable Lender would have been entitled to receive with respect to the participation sold to such Participant, unless the sale of the participation to such Participant is made with the Borrower's prior written consent. A Participant that would be a Foreign Lender if it were a Lender shall not be entitled to the benefits of Section 3.13 unless the Borrower is notified of the participation sold to such Participant and such Participant agrees, for the benefit of the Borrower, to comply with Section 3.13(f) as though it were a Lender.

(f) Any Lender may at any time pledge or assign a security interest in all or any portion of its rights under this Credit Agreement (including under its Note, if any) to secure obligations of such Lender, including any pledge or assignment to secure obligations to a Federal Reserve Bank; provided that no such pledge or assignment shall release such Lender from any of its obligations hereunder or substitute any such pledgee or assignee for such Lender as a party hereto.

(g) Notwithstanding anything to the contrary contained herein, any Lender (a "Granting Lender") may grant to a special purpose funding vehicle identified as such in writing from time to time by the Granting Lender to the Administrative Agent and the Borrower (an "SPC") the option to provide all or any part of any Loan that such Granting Lender would otherwise be obligated to make pursuant to this Credit Agreement; provided that (i) nothing herein shall constitute a commitment by any SPC to fund any Loan, and (ii) if an SPC elects not to exercise such option or otherwise fails to make all or any part of such Loan, the Granting Lender shall be obligated to make such Loan pursuant to the terms hereof. Each party hereto hereby agrees that (A) neither the grant to any SPC nor the exercise by any SPC of such option shall increase the costs or expenses or otherwise increase or change the obligations of the Borrower under this Credit Agreement (including its obligations under Sections 3.9, 3.12, 3.13 and 3.14), (B) no SPC shall be liable for any indemnity or similar payment obligation under this Credit Agreement for which a Lender would be liable, and (C) the Granting Lender shall for all purposes, including the approval of any amendment, waiver or other modification of any provision of any Credit Document, remain the lender of record hereunder. The making of a Committed Loan by an SPC hereunder shall utilize the Commitment of the Granting Lender to the same extent, and as if, such Loan were made by such Granting Lender. In furtherance of the foregoing, each party hereto hereby agrees (which agreement shall survive the termination of this Credit Agreement) that, prior to the date that is one year and one day after the payment in full of all outstanding commercial paper or other senior debt of any SPC, it will not institute against, or join any other Person in instituting against, such SPC any bankruptcy, reorganization, arrangement, insolvency, or liquidation proceeding under the Laws of the United States or any State thereof. Notwithstanding anything to the contrary contained herein, any SPC may
(i) with notice to, but without prior consent of the Borrower and the Administrative Agent and without paying any processing fee therefor, assign all or any portion of its right to receive payment with respect to any Loan to the Granting Lender and (ii) disclose on a confidential basis any non-public information relating to its funding of Loans to any rating agency, commercial paper dealer or provider of any surety or guarantee or credit or liquidity enhancement to such SPC.

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(i) Notwithstanding anything to the contrary contained herein, any Lender that is a Fund may create a security interest in all or any portion of the Loans owing to it and the Note, if any, held by it to the trustee for holders of obligations owed, or securities issued, by such Fund as security for such obligations or securities, provided that unless and until such trustee actually becomes a Lender in compliance with the other provisions of this Section 11.3, (i) no such pledge shall release the pledging Lender from any of its obligations under the Credit Documents and (ii) such trustee shall not be entitled to exercise any of the rights of a Lender under the Credit Documents even though such trustee may have acquired ownership rights with respect to the pledged interest through foreclosure or otherwise.

(j) Notwithstanding anything to the contrary contained herein, if at any time Bank of America assigns all of its Commitment and Loans pursuant to subsection (b) above, Bank of America may upon 30 days' notice to the Borrower and the Lenders, resign as L/C Issuer. In the event of any such resignation as L/C Issuer, the Borrower shall be entitled to appoint from among the Lenders a successor L/C Issuer hereunder; provided, however, that no failure by the Borrower to appoint any such successor shall affect the resignation of Bank of America as L/C Issuer. If Bank of America resigns as L/C Issuer, it shall retain all the rights and obligations of the L/C Issuer hereunder with respect to all Letters of Credit outstanding as of the effective date of its resignation as L/C Issuer and all L/C Obligations with respect thereto (including the right to require the Lenders to make Loans or fund risk participations pursuant to Section 2.2.

11.4 No Waiver; Remedies Cumulative.

No failure or delay on the part of the Administrative Agent or any Lender in exercising any right, power or privilege hereunder or under any other Credit Document and no course of dealing between the Borrower and the Administrative Agent or any Lender shall operate as a waiver thereof; nor shall any single or partial exercise of any right, power or privilege hereunder or under any other Credit Document preclude any other or further exercise thereof or the exercise of any other right, power or privilege hereunder or thereunder. The rights and remedies provided herein are cumulative and not exclusive of any rights or remedies which the Administrative Agent or any Lender would otherwise have. No notice to or demand on the Borrower in any case shall entitle the Borrower to any other or further notice or demand in similar or other circumstances or constitute a waiver of the rights of the Administrative Agent or the Lenders to any other or further action in any circumstances without notice or demand.

11.5 Attorney Costs, Expenses, Taxes and Indemnification by

Borrower.

(a) The Borrower agrees (i) to pay or reimburse the Administrative Agent and the Arranger for all costs and expenses incurred in connection with the development, preparation, negotiation and execution of this Credit Agreement and the other Credit Documents and any amendment, waiver, consent or other modification of the provisions hereof and thereof (whether or not the transactions

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contemplated hereby or thereby are consummated), and the consummation and administration of the transactions contemplated hereby and thereby, including all reasonable fees and expenses of legal counsel, and (ii) to pay or reimburse the Administrative Agent and each Lender for all costs and expenses incurred in connection with the enforcement, attempted enforcement, or preservation of any rights or remedies under this Credit Agreement or the other Credit Documents (including all such costs and expenses incurred during any "workout" or restructuring in respect of the Borrower Obligations and during any legal proceeding, including any proceeding under any Debtor Relief Law), including all reasonable fees and expenses of legal counsel. The foregoing costs and expenses shall include all search, filing, recording, and appraisal charges and fees and taxes related thereto, and other out-of-pocket expenses incurred by the Administrative Agent and the Arranger and the cost of independent public accountants and other outside experts retained by the Administrative Agent, the Arranger or any Lender. Other than costs and expenses payable in connection with the closing of the transactions contemplated by this Credit Agreement pursuant to Section
11.5(a) (which shall be payable on the Closing Date unless otherwise agreed by the Administrative Agent and the Arranger), all amounts due under this Section 11.5 shall be payable within ten Business Days after demand therefor. The agreements in this Section shall survive the termination of the Commitments and repayment of all other Borrower Obligations.

(b) Whether or not the transactions contemplated hereby are consummated, the Borrower shall indemnify and hold harmless each Agent-Related Person, each Lender and their respective Affiliates, directors, officers, employees, counsel, agents and attorneys-in-fact (collectively the "Indemnitees") from and against any and all liabilities, obligations, losses, damages, penalties, claims, demands, actions, judgments, suits, costs, expenses and disbursements (including the reasonable fees and expenses of legal counsel) of any kind or nature whatsoever which may at any time be imposed on, incurred by or asserted against any such Indemnitee in any way relating to or arising out of or in connection with (i) the execution, delivery, enforcement, performance or administration of any Credit Document or any other agreement, letter or instrument delivered in connection with the transactions contemplated thereby or the consummation of the transactions contemplated thereby, (ii) any Commitment, Loan or Letter of Credit or the use or proposed use of the proceeds therefrom (including any refusal by the L/C Issuer to honor a demand for payment under a Letter of Credit if the documents presented in connection with such demand do not strictly comply with the terms of such Letter of Credit), or (iii) any actual or alleged presence or release of Hazardous Substances on or from any property currently or formerly owned or operated by the Borrower, any Subsidiary of the Borrower, or any Environmental Claim related in any way to the Borrower or any Subsidiary of the Borrower, or (iv) any actual or prospective claim, litigation, investigation or proceeding relating to any of the foregoing, whether based on contract, tort or any other theory (including any investigation of, preparation for, or defense of any pending or threatened claim, investigation, litigation or proceeding) and regardless of whether any Indemnitee is a party thereto (all the foregoing, collectively, the "Indemnified Liabilities"), in all cases, whether or not caused by or arising, in whole or in part, out of the negligence of the Indemnitee; provided that such indemnity shall not, as to any Indemnitee, be available to the extent that such liabilities, obligations, losses, damages, penalties, claims, demands, actions, judgments, suits, costs, expenses or disbursements are determined by a

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court of competent jurisdiction by final and nonappealable judgment to have resulted from the gross negligence or willful misconduct of such Indemnitee. No Indemnitee shall be liable for any damages arising from the use by others of any information or other materials obtained through IntraLinks or other similar information transmission systems in connection with this Credit Agreement, nor shall any Indemnitee have any liability for any indirect or consequential damages relating to this Credit Agreement or any other Credit Document or arising out of its activities in connection herewith or therewith (whether before or after the Closing Date). All amounts due under this Section 11.5 shall be payable within ten Business Days after demand therefor. The agreements in this Section shall survive the resignation of the Administrative Agent, the replacement of any Lender, the termination of the Commitments and the repayment, satisfaction or discharge of all the other Borrower Obligations.

11.6 Amendments, Waivers and Consents.

Neither this Credit Agreement nor any other Credit Document nor any of the terms hereof or thereof may be amended, changed, waived, discharged or terminated unless such amendment, change, waiver, discharge or termination is in writing and signed by the Required Lenders and the Borrower; provided that no such amendment, change, waiver, discharge or termination shall, without the consent of each Lender directly affected thereby:

(a) extend the Maturity Date;

(b) reduce the rate or extend the time of payment of interest (other than as a result of waiving the applicability of any post-default increase in interest rates on the Revolving Loans or fees hereunder;

(c) reduce or waive the principal amount of any Revolving Loan or extend the time of payment thereof;

(d) increase or extend the Commitment of a Lender (it being understood and agreed that a waiver of any Default or Event of Default or a waiver of any mandatory reduction in the Commitments shall not constitute a change in the terms of any Commitment of any Lender);

(e) release the Borrower from its obligations or consent to the assignment or transfer by the Borrower of any of its rights and obligations under (or in respect of) the Credit Documents;

(f) amend, modify or waive any provision of this Section 11.6 or Sections 3.7, 3.8, 9.1(a), 11.2, 11.3 or 11.5; or

(g) reduce any percentage specified in, or otherwise modify, the definition of Required Lenders.

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Notwithstanding the above, (i) no provision of Section 3.4(d) or
Section 10 may be amended or modified without the consent of the Administrative Agent, (ii) no provision of this Credit Agreement or any other Credit Document that addresses the rights or obligations of the Administrative Agent may be amend or modified without prior written consent of the Administrative Agent and
(iii) no provision of Section 2.2 and no other provision of this Credit Agreement or any other Credit Document that addresses the rights or obligations of the L/C Issuer may be amended or modified without the prior written consent of the L/C Issuer.

Each Lender understands and agrees that if such Lender is a Defaulting Lender then, notwithstanding the provisions of this Section 11.6, it shall not be entitled to vote on any matter requiring the consent of the Required Lenders or to object to any matter requiring the consent of all the Lenders; provided, however, that all other benefits and obligations under the Credit Documents shall apply to such Defaulting Lender.

Notwithstanding the fact that the consent of all the Lenders is required in certain circumstances as set forth above, (A) each Lender is entitled to vote as such Lender sees fit on any reorganization plan that affects the Borrower Obligations, and each Lender acknowledges that the provisions of
Section 1126(c) of the Bankruptcy Code supersede the unanimous consent provisions set forth herein and (B) the Required Lenders may consent to allow a Borrower to use cash collateral in the context of a bankruptcy or insolvency proceeding.

11.7 Counterparts.

This Credit Agreement may be executed in any number of counterparts, each of which when so executed and delivered shall be an original, but all of which shall constitute one and the same instrument.

11.8 Headings.

The headings of the sections and subsections hereof are provided for convenience only and shall not in any way affect the meaning or construction of any provision of this Credit Agreement.

11.9 Survival of Indemnification and Representations and

Warranties.

(a) Survival of Indemnification. All indemnities set forth herein shall survive the execution and delivery of this Credit Agreement, the making of any Credit Extension and the repayment of the Revolving Loans and other Borrower Obligations and the termination of the Commitments hereunder.

(b) Survival of Representations and Warranties. All representations and warranties made hereunder and in any other Credit Document or other document delivered pursuant hereto or thereto or in connection herewith or therewith shall survive the execution and delivery hereof and thereof. Such representations and warranties have been or will be relied upon by the Administrative Agent and each Lender, regardless of any investigation made by the Administrative Agent or any Lender or on their behalf and notwithstanding that the Administrative Agent or any Lender may have had notice or knowledge of any Default or Event of Default at the time of any Credit Extension, and shall continue in full force and effect as long as any Loan or any other Borrower Obligation hereunder shall remain unpaid or unsatisfied or any Letter of Credit shall remain outstanding.

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11.10 Governing Law; Service.

THIS CREDIT AGREEMENT AND THE OTHER CREDIT DOCUMENTS AND THE RIGHTS AND OBLIGATIONS OF THE PARTIES HEREUNDER AND THEREUNDER SHALL BE GOVERNED BY AND CONSTRUED AND INTERPRETED IN ACCORDANCE WITH THE LAWS OF THE STATE OF NEW YORK (INCLUDING SECTIONS 5-1401 AND 5-1402 OF THE NEW YORK GENERAL OBLIGATIONS LAW, BUT EXCLUDING ALL OTHER CHOICE OF LAW AND CONFLICTS OF LAW RULES). The Borrower irrevocably consents to the service of process in any action or proceeding with respect to this Credit Agreement or any other Credit Document by the mailing of copies thereof by registered or certified mail, postage prepaid, to it at the address for notices pursuant to Section 11.1, such service to become effective ten days after such mailing. Nothing herein shall affect the right of a Lender to serve process in any other manner permitted by Law.

11.11 Waiver of Jury Trial; Waiver of Consequential Damages.

EACH OF THE PARTIES TO THIS CREDIT AGREEMENT HEREBY IRREVOCABLY WAIVES ALL RIGHT TO TRIAL BY JURY IN ANY ACTION, PROCEEDING OR COUNTERCLAIM ARISING OUT OF OR RELATING TO THIS CREDIT AGREEMENT, ANY OF THE OTHER CREDIT DOCUMENTS OR THE TRANSACTIONS CONTEMPLATED HEREBY AND THEREBY. Each of the parties to this Credit Agreement agrees not to assert any claim against any other party hereto, Administrative Agent, any Lender, any of their Affiliates, or any of their respective directors, officers, employees, attorneys or agents, on any theory of liability, for special, indirect, consequential or punitive damages arising out of or otherwise relating to any of the transactions contemplated herein and in the other Credit Documents.

11.12 Severability.

If any provision of any of the Credit Documents is determined to be illegal, invalid or unenforceable, such provision shall be fully severable and the remaining provisions shall remain in full force and effect and shall be construed without giving effect to the illegal, invalid or unenforceable provisions.

11.13 Further Assurances.

The Borrower agrees, upon the request of the Administrative Agent, to promptly take such actions, as reasonably requested, as is necessary to carry out the intent of this Credit Agreement and the other Credit Documents.

11.14 Confidentiality.

Each Lender agrees that it will use reasonable efforts to keep confidential any non-public information from time to time supplied to it under any Credit Document; provided, however, that nothing herein shall prevent the disclosure of any such information to (a) the extent a Lender in good faith believes such disclosure is required by Law or judicial process, (b) counsel for

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a Lender or to its accountants, (c) bank examiners or auditors or comparable Persons, (d) any Affiliate of a Lender, (e) any other Lender, or any assignee, transferee or Participant, or any potential assignee, transferee or Participant, of all or any portion of any Lender's rights under this Credit Agreement who is notified of the confidential nature of such information or (f) any other Person in connection with (i) any litigation to which any one or more of the Lenders is a party if required by a court of Law of competent jurisdiction or (ii) any proceeding to enforce such Lender's rights hereunder, under any other Credit Document or under any Hedging Agreement. No Lender shall have any obligation under this Section 11.14 to the extent any such information becomes available on a non-confidential basis from a source other than a Borrower or that any information becomes publicly available other than by a breach of this Section 11.14 by any Lender or representative thereof.

11.15 Entirety.

This Credit Agreement together with the other Credit Documents, the Fee Letter and any confidentiality agreements between the Borrower and any Lender represent the entire agreement of the parties hereto and thereto, and supersede all prior agreements and understandings, oral or written, if any, including any commitment letters or correspondence relating to the Credit Documents or the transactions contemplated herein and therein.

11.16 Binding Effect; Continuing Agreement.

(a) This Credit Agreement shall become effective at such time when all of the conditions set forth in Section 5.1 have been satisfied or waived by the Lenders and it shall have been executed by the Borrower and the Administrative Agent, and the Administrative Agent shall have received copies hereof (telefaxed or otherwise) which, when taken together, bear the signatures of each Lender, and thereafter this Credit Agreement shall be binding upon and inure to the benefit of the Borrower, the Administrative Agent and each Lender and their respective successors and assigns.

(b) This Credit Agreement shall be a continuing agreement and shall remain in full force and effect until all Revolving Loans, interest, fees and other Borrower Obligations have been paid in full and all Letters of Credit and Commitments have been terminated. Upon termination, the Borrower shall have no further obligations (other than the indemnification provisions and other provisions that by their terms survive) under the Credit Documents; provided that should any payment, in whole or in part, of the Borrower Obligations be rescinded or otherwise required to be restored or returned by the Administrative Agent or any Lender, whether as a result of any proceedings in bankruptcy or reorganization or otherwise, then the Credit Documents shall automatically be reinstated and all amounts required to be restored or returned and all costs and expenses incurred by the Administrative Agent or any Lender in connection therewith shall be deemed included as part of the Borrower Obligations.

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11.17 Regulatory Statement.

Pursuant to the terms of an order issued by the New Mexico Public Regulation Commission, the Borrower is required to include the following separateness covenants in any debt instrument:

(a) The Borrower and its corporate parent, PNM Resources, Inc. ("Parent") are being operated as separate corporate and legal entities. In agreeing to make loans to Parent, Parent's lenders are relying solely on the creditworthiness of Parent based on the assets owned by Parent, and the repayment of the loan will be made solely from the assets of Parent and not from any assets of the Borrower; and the Parent's lenders will not take any steps for the purpose of procuring the appointment of an administrative receiver or the making of an administrative order for instituting any bankruptcy, reorganization, insolvency, wind up or liquidation or any like proceeding under applicable law in respect of the Borrower.

(b) Notwithstanding any of the foregoing set forth in this Section 11.17, the Borrower and the Lenders hereby acknowledge and agree that (i) this Credit Agreement and the Revolving Notes evidence Indebtedness of the Borrower and not of the Parent, (ii) the Lenders are not, and shall not at any time be deemed to be, "Parent's lenders" under this Credit Agreement and the Revolving Notes and the foregoing covenants are therefore wholly inapplicable and ineffective under the terms of this Credit Agreement and the Revolving Notes,
(iii) as set forth in this Credit Agreement and the Revolving Notes, the Borrower is responsible for the repayment of all amounts outstanding hereunder,
(iv) the Lenders reserve all rights to pursue any and all remedies available at law and otherwise (including, without limitation, in bankruptcy) should the Borrower breach any of the its obligations under this Credit Agreement and/or the Revolving Notes.

[REMAINDER OF PAGE INTENTIONALLY LEFT BLANK]

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Each of the parties hereto has caused a counterpart of this Credit Agreement to be duly executed and delivered as of the date first above written.

BORROWER:

PUBLIC SERVICE COMPANY OF NEW MEXICO,
a New Mexico corporation

By:      /s/ T. R. Horn
   -----------------------------------------------
Name:    T. R. Horn
     ---------------------------------------------
Title:   Vice President and Treasurer
      --------------------------------------------

LENDERS:

BANK OF AMERICA, N.A.,
individually in its capacity as a Lender and in
its capacity as Administrative Agent and L/C Issuer

By:      /s/ Michelle A. Schoenfeld
   ----------------------------------------------
Name:    Michelle A. Schoenfeld
     --------------------------------------------
Title:   Principal
      -------------------------------------------

S-1

                                 SCHEDULE 1.1(a)

                                 PRO RATA SHARES
                                 ---------------

-------------------------------------------- ---------------- ---------------
                Lender                          Commitment    Pro Rata Share
-------------------------------------------- ---------------- ---------------

Bank of America, N.A                          $25,000,000.00  12.8205128205%
-------------------------------------------- ---------------- ---------------
Fleet National Bank                            25,000,000.00  12.8205128205%
-------------------------------------------- ---------------- ---------------
Wachovia Bank, National Association            25,000,000.00  12.8205128205%
-------------------------------------------- ---------------- ---------------
Bank of Albuquerque, N.A.                      20,000,000.00  10.2564102564%
-------------------------------------------- ---------------- ---------------
Wells Fargo Bank, National Association         20,000,000.00  10.2564102564%
-------------------------------------------- ---------------- ---------------
JPMorgan Chase Bank                            15,000,000.00   7.6923076923%
-------------------------------------------- ---------------- ---------------
Citibank NA                                    15,000,000.00   7.6923076923%
-------------------------------------------- ---------------- ---------------
Bank of the West                               15,000,000.00   7.6923076923%
-------------------------------------------- ---------------- ---------------
Compass Bank                                   15,000,000.00   7.6923076923%
-------------------------------------------- ---------------- ---------------
Mellon Bank, N.A.                              10,000,000.00   5.1282051282%
-------------------------------------------- ---------------- ---------------
Morgan Stanley Bank                            10,000,000.00   5.1282051282%
-------------------------------------------- ---------------- ---------------
                                     Total:  $195,000,000.00       100%
-------------------------------------------- ---------------- ---------------


SCHEDULE 1.1(c)

EXISTING LETTERS OF CREDIT

ISSUER: JP Morgan Chase Bank

$3,000,000.0      Expiration Date: January 4, 2003   L/C No. P-360138
---------------------------------------------------------------------

Beneficiary:      The California Power Exchange Corporation
                  200 South Los Robles Ste 400
                  Pasadena, California 91011-2482

$500,000.00       Expiration Date: March 11, 2003    L/C No. P-227635
---------------------------------------------------------------------

Beneficiary:      California Independent System Operator Corporation
                  Blue Raven Road
                  Folsom, California 95630


SCHEDULE 6.18

MATERIAL LEASES

Page 1

         Description                                               Expiration         Annual Rent
         -----------                                               ----------         -----------

Palo Verde Unit 1

Facility Lease dated as of  December 16, 1985 between              1/15/2015       $  5,580,122.54
PNM and State Street Bank and Trust Company,( as successor
to The First National Bank of Boston), as Owner Trustee under
a Trust Agreement dated as of  December 16, 1985, with MFS
Leasing Corp. as Owner Participant, as amended.

Facility Lease dated as of  December 16, 1985 between              1/15/2015       $ 15,693,862.76
PNM and State Street Bank and Trust Company, (as successor
to The First National Bank of Boston), as Owner Trustee under
a Trust Agreement dated as of  December 16, 1985, with Daimler
Chrysler Services North America LLC (as successor to Chrysler
Financial Corporation), as Owner Participant, as amended.

Facility Lease dated as of  December 15, 1986 between              1/15/2015       $  4,757,769.00
PNM and State Street Bank and Trust Company, (as successor
to The First National Bank of Boston), as Owner Trustee under
a Trust Agreement dated as of  December 15, 1986, with Palo
Verde 1- PNM [December 75] Corporation (successor-in-interest
to  Chase Manhattan Realty Leasing Corporation), as Owner
Participant (Unit 1), as amended.

Facility Lease dated as of July 31, 1986 between                   1/15/2015       $  6,974,313.00
PNM and State Street Bank and Trust Company, (as successor
to The First National Bank of Boston), as Owner Trustee under
a Trust Agreement dated as of July 31, 1986, with Palo
Verde 1- PNM [August 50] Corporation (successor-in-interest
to  Chase Manhattan Realty Leasing Corporation), as Owner
Participant  (Unit 1), as amended.


Total - Unit 1                                                                     $ 33,006.067.10


SCHEDULE 6.18
MATERIAL LEASES

Page 2

         Description                                                  Expiration         Annual Rent
         -----------                                                  ----------         -----------

Palo Verde Unit 2

Facility Lease dated as of August  12, 1986 between                    1/15/2016      $  5,742,060.00
PNM and State Street Bank and Trust Company,( as successor
to The First National Bank of Boston), as Owner Trustee under
a Trust Agreement dated as of  August 12, 1986, with MFS
Leasing Corp. as Owner Participant, as amended.

Facility Lease dated as of August 12,  1986 between                    1/15/2016      $  9,958,478.04
PNM and State Street Bank and Trust Company, (as successor
to The First National Bank of Boston), as Owner Trustee under
a Trust Agreement dated as of August 12, 1986, with CGI
Capital, Inc., as Owner Participant, as amended.

Facility Lease dated as of August 12, 1986 between                     1/15/2016      $  9,569,653.00
PNM and State Street Bank and Trust Company, (as successor
to The First National Bank of Boston), as Owner Trustee under
a Trust Agreement dated as of August 12, 1986, with Palo Verde
Leasing Corporation (successor-in-interest to First Chicago Lease
Holdings, Inc.) as Owner Participant, as amended.

Facility Lease dated as of August 12, 1986 between                     1/15/2016      $  4,743,012.00
PNM and State Street Bank and Trust Company, (as successor
to The First National Bank of Boston), as Owner Trustee under
a Trust Agreement dated as of August 12, 1986, with  MFS
(successor-in-interest to Beneficial Leasing Group, Inc.),
as Owner Participant, as amended.

Facility Lease dated as of December 15, 1986 between                   1/15/2016      $  3,272,560.40
PNM and State Street Bank and Trust Company, (as successor
to The First National Bank of Boston), as Owner Trustee under
a Trust Agreement dated as of December 15, 1986, with Palo
Verde 2- PNM [December 35] Corporation (successor-in-interest
to  Chase Manhattan Realty Leasing Corporation), as Owner
Participant  (Unit 2), as amended.


Total - Unit 2                                                                        $ 33,285.763.44


SCHEDULE 6.18
MATERIAL LEASES

Page 3

         Description                                       Expiration            Annual Rent
         -----------                                       ----------            -----------

Eastern Interconnection Project (EIP)

Amended and Restated Lease dated as of September 1,         4/1/2015          $  4,009,766.52*
1993, between PNM as Lessee, and  State Street Bank                           $  4,487,119.64
and Trust Company,( as successor to The First National
Bank of Boston), as Owner Trustee under a Trust
Agreement dated as of January 2, 1985, with DCC
Project Finance Two, Inc., as Lessor.

Amended and Restated Lease dated as of September 1,         4/1/2015          $  2,675,739.30*
1993, between PNM as Lessee, and  State Street Bank                           $  2,844,913.50
and Trust Company,( as successor to The First National
Bank of Boston), as Owner Trustee under a Trust
Agreement dated as of January 2, 1985, with General
Foods Credit Corporation, as Lessor.

Total EIP                                                                     $ 6, 685,505.82*
                                                                              $  7,332,033.14

                                                                                  * 1994 Only


SCHEDULE 6.19

MATERIAL LEASE INTEREST PAYMENTS AND DISCOUNT RATE


Schedule 11.1

Notices

PUBLIC SERVICE COMPANY OF NEW MEXICO:

Public Service Company of New Mexico
414 Silver Avenue, MS 2702
Albuquerque, NM 87102
Attention: Kirk Meyer
Telephone: 505-241-4529
Facsimile: 505-241-2369
Electronic Mail: kmeyer@pnm.com

ADMINISTRATIVE AGENT:

Administrative Agent's Office
(for payments and Requests for Credit Extensions):
Bank of America, N.A.
Bank of America Plaza
901 Main St., 14th Floor
Mail Code: TX1-492-14-14
Dallas, TX 75202-3714
Attention: Charlotte A. Conn
Telephone: 214.209.3606
Facsimile: 214.290.9653
Electronic Mail: charlotte.a.conn@bankofamerica.com Account No.: 1292000883
Ref: Public Service Co of New Mexico
ABA# 111000012

Other Notices as Administrative Agent:
Bank of America, N.A.
Agency Management
Bank of America Plaza
901 Main St., 14th Floor
Mail Code: TX1-492-14-11
Dallas, TX 75202-3714
Attention: Ramon Garcia
Telephone: 214.209.4126
Facsimile: 214.290.9520
Electronic Mail: ramon.garcia@bankofamerica.com

L/C ISSUER:

Bank of America, N.A.
Trade Operations-Los Angeles #22621
333 S. Beaudry Avenue, 19th Floor
Mail Code: CA9-703-19-23
Los Angeles, CA 90017-1466

Attention:        Sandra Leon
                  Vice President
Telephone:  213.345.5231
Facsimile:  213.345.6694

Electronic Mail: Sandra.Leon@bankofamerica.com

LENDERS:

Bank of America, N.A.
Bank of America Corporate Center
100 N. Tryon Street, 16th Floor
Charlotte, NC 28255
Attn: Michelle A. Schoenfeld
Telephone: 704.386.1432
Facsimile: 704.386.1319
Electronic Mail: michelle.a.schoenfeld@bankofamerica.com

Bank of Albuquerque, N.A.
201 Third Street NW, Suite 1400
Albuquerque, NM 87102
Attn: Richard W. Burdick
Telephone: 505.222.8441
Facsimile: 505.222.8481
Electronic Mail: rburdick@bokf.com

Mellon Bank, N.A.
One Mellon Center
Room 151-4530
Pittsburgh, PA 15258
Attn: Mark W. Rogers
Telephone: 412-234-1888
Facsimile: 412-236-1840
Electronic Mail: rogers.mw@mellon.com


Morgan Stanley Bank
750 Seventh Avenue, 11th Floor
New York, NY 10020
Attn: Joseph DiTomaso
Telephone: 212-537-1470
Facsimile: 212-537-1867/1866
Electronic Mail: Joseph.DiTomaso@morganstanley.com

Compass Bank
2444 Louisiana Blvd., NE
Suite 200
Albuquerque, NM 87110
Attn: Abran C. Villegas
Telephone: 505-888-9038
Facsimile: 505-888-9176
Electronic Mail: abran.villegas@compassbnk.com

Citibank NA
388 Greenwich Street, 23rd Floor
New York, NY 10013
Attn: Stuart Glen
Telephone: 212-816-8553
Facsimile: TBD
Electronic Mail: Stuart.j.glen@citigroup.com

Fleet National Bank
Energy/Utilities, MA, DE 10009H
100 Federal Street
Boston, MA 02110
Attn: Stephen Hoffman
Telephone: 617-434-6520
Facsimile: 617-434-3652
Electronic Mail: stephen_j_hoffman@fleet.com

Bank of the West
500 Marquette NW, 14th Floor
Albuquerque, NM 87102
Attn: J. Chesley Steel
Telephone: 505-843-9180
Facsimile: 505-843-9164
Electronic Mail: csteel@bankofthewest.com


Wells Fargo Bank, N.A.
200 Lomas Blvd. NW
MAC Q2129-013
Albuquerque, NM 87102
Attn: Richard A. Zeigner
Telephone: 505-766-6239
Facsimile: 505-247-4639
Electronic Mail: ziegnerr@wellsfargo.com

Wachovia Bank, National Association
301 S. College Street
Charlotte, NC 28288
Attn: Joe Dancy
Telephone: 704-383-4748
Facsimile: 704-374-2570
Electronic Mail: Joe.dancy@wachovia.com

JPMorgan Chase Bank
270 Park Avenue, 4th Floor
New York, NY 10017
Attn: Thomas Hou
Telephone: 212-270-6072
Facsimile: 212-270-3089
Electronic Mail: Thomas.Hou@jpmorgan.com


EXHIBIT 2.1(b)

FORM OF
NOTICE OF BORROWING

TO:           BANK OF AMERICA, N.A., as Administrative Agent

RE:           Credit Agreement dated as of December 19, 2002 among Public
              Service Company of New Mexico (the "Borrower"), Bank of America,
              N.A., as Administrative Agent, and the Lenders identified
              therein (as the same may be amended, modified, extended or
              restated from time to time, the "Credit Agreement")

DATE:         _____________, ______


1.       This Notice of Borrowing is made pursuant to the terms of the Credit
         Agreement. All capitalized terms used herein unless otherwise defined
         shall have the meanings set forth in the Credit Agreement.

2.       Please be advised that the Borrower is requesting Revolving Loans on
         the terms set forth below:

                  (a)      Principal amount of requested
                           Revolving Loans                $___________________

                  (b)      Date of requested Revolving
                           Loans                           ___________________

                  (c)      Interest rate applicable to the

requested Revolving Loans:

(i) ________Base Rate

(ii) ________Adjusted Eurodollar Rate for an Interest Period of:

________ one month ________ two months ________ three months ________ six months

3. Subsequent to the funding of the requested Revolving Loan, the aggregate amount of Revolving Loans outstanding plus the aggregate amount of L/C Obligations outstanding will be $________________ which is less than or equal the Revolving Committed Amount.


4. The representations and warranties made by the Borrower in any Credit Document are true and correct in all material respects at and as if made on the date of the requested Revolving Loans except to the extent they expressly relate to an earlier date.

5. No Default or Event of Default exists or shall be continuing either prior to or after giving effect to the Revolving Loans made pursuant to this Notice of Borrowing.

PUBLIC SERVICE COMPANY OF NEW MEXICO,
a New Mexico corporation

By:

Name:
Title:

Exhibit 2.1(e)

FORM OF
REVOLVING NOTE

Lender: ______________ _____________, 2002

FOR VALUE RECEIVED, PUBLIC SERVICE COMPANY OF NEW MEXICO, a New Mexico corporation (the "Borrower"), hereby promises to pay to the order of the Lender referenced above (the "Lender"), at the Administrative Agent's Office set forth in that certain Credit Agreement dated as of December 19, 2002 (as amended, modified, extended or restated from time to time, the "Credit Agreement") among the Borrower, the Lenders party thereto (including the Lender) and Bank of America, N.A., as Administrative Agent (the "Administrative Agent") (or at such other place or places as the holder of this Revolving Note may designate), the aggregate unpaid principal amount of the Revolving Loans made by the Lender to the Borrower under the Credit Agreement, in lawful money and in immediately available funds, on the dates and in the principal amounts provided in the Credit Agreement, and to pay interest on the unpaid principal amount of each Revolving Loan made by the Lender, at such office, in like money and funds, for the period commencing on the date of each Revolving Loan until each Revolving Loan shall be paid in full, at the rates per annum and on the dates provided in the Credit Agreement.

This Note is one of the Revolving Notes referred to in the Credit Agreement and evidences Revolving Loans made by the Lender thereunder. Capitalized terms used in this Revolving Note have the respective meanings assigned to them in the Credit Agreement and the terms and conditions of the Credit Agreement are expressly incorporated herein and made a part hereof.

The Credit Agreement provides for the acceleration of the maturity of the Revolving Loans evidenced by this Revolving Note upon the occurrence of certain events (and for payment of collection costs in connection therewith) and for prepayments of Revolving Loans upon the terms and conditions specified therein. In the event this Revolving Note is not paid when due at any stated or accelerated maturity, the Borrower agrees to pay, in addition to principal and interest, all costs of collection, including reasonable attorney fees.

The date, amount, type, interest rate and duration of Interest Period (if applicable) of each Revolving Loan made by the Lender to the Borrower, and each payment made on account of the principal thereof, shall be recorded by the Lender on its books; provided that the failure of the Lender to make any such recordation or endorsement shall not affect the obligations of the Borrower to make a payment when due of any amount owing under the Credit Agreement or under this Revolving Note in respect of the Revolving Loans to be evidenced by this Revolving Note, and each such recordation or endorsement shall be prima facie evidence of such information, absent manifest error.

Except as permitted by Section 11.3(b) of the Credit Agreement, this Revolving Note may not be assigned by the Lender to any other Person.


THIS REVOLVING NOTE SHALL BE GOVERNED BY, AND CONSTRUED IN ACCORDANCE WITH,
THE LAWS OF THE STATE OF NEW YORK.

IN WITNESS WHEREOF, the Borrower has caused this Revolving Note to be executed as of the date first above written.

PUBLIC SERVICE COMPANY OF NEW MEXICO,
a New Mexico corporation

By:

Name:
Title:

EXHIBIT 2.3

FORM OF NOTICE OF CONTINUATION/CONVERSION

TO:         BANK OF AMERICA, N.A., as Administrative Agent

RE:         Credit Agreement dated as of December 19, 2002 among Public Service
            Company of New Mexico (the "Borrower"), Bank of America, N.A., as
            Administrative Agent, and the Lenders named therein (as the same may
            be amended, modified, extended or restated from time to time, the
            "Credit Agreement")

DATE:       _____________, 200_

--------------------------------------------------------------------------------

1.       This Notice of Continuation/Conversion is made pursuant to the terms of
         the Credit Agreement. All capitalized terms used herein unless
         otherwise defined shall have the meanings set forth in the Credit
         Agreement.

2.       Please be advised that the Borrower is requesting that a portion of the
         current outstanding Revolving Loans in the amount of $ currently
         accruing interest at
         be extended or converted as of _____________, 200__ at the interest
         rate option set forth in paragraph 3 below.

3.       The interest rate option applicable to the extension or conversion of
         all or part of the existing Revolving Loans (as set forth above) shall
         be:

         a. ________ the Base Rate

         b. ________ the Adjusted Eurodollar Rate for an Interest Period of:

                                    ________ one month
                                    ________ two months
                                    ________ three months
                                    ________ six months

4.       As of the date hereof, no Default or Event of Default has occurred and
         is continuing.


                                          PUBLIC SERVICE COMPANY OF NEW MEXICO,
                                          a New Mexico corporation


                                          By:
                                             ---------------------------------
                                          Name:
                                               -------------------------------
                                          Title:
                                                ------------------------------


EXHIBIT 7.1(c)

FORM OF
COMPLIANCE CERTIFICATE

TO:           BANK OF AMERICA, N.A., as Administrative Agent

RE:           Credit Agreement dated as of December 19, 2002 among Public
              Service Company of New Mexico (the "Borrower"), Bank of America,
              N.A. as Administrative Agent, and the Lenders named therein (as
              the same may be amended, modified, extended or restated from time
              to time, the "Credit Agreement")

DATE:         _____________, 200__


Pursuant to the terms of the Credit Agreement, I, ______________, Chief Financial Officer of Public Service Company of New Mexico, hereby certify on behalf of the Borrower that, as of the quarter ending ________, 200__, the statements below are accurate and complete in all respects (all capitalized terms used below shall have the meanings set forth in the Credit Agreement):

a. Attached hereto as Schedule 1 are calculations (calculated as of the date of the financial statements referred to in paragraph c. below) demonstrating compliance by the Borrower with the financial covenants contained in Section 7.2 of the Credit Agreement.

b. No Default or Event of Default exists under the Credit Agreement, except as indicated on a separate page attached hereto, together with an explanation of the action taken or proposed to be taken by the Borrower with respect thereto.


c. The quarterly/annual financial statements for the fiscal quarter/year ended __________, 200__ which accompany this certificate fairly present in all material respects the financial condition of the Borrower and its Subsidiaries and have been prepared in accordance with GAAP, subject to changes resulting from normal year-end audit adjustments and except that the quarterly financial statements have fewer footnotes than annual statements.

PUBLIC SERVICE COMPANY OF NEW MEXICO,
a New Mexico corporation

By:

Name:
Title:

SCHEDULE 1 TO COMPLIANCE CERTIFICATE

A.       Compliance with Section 7.2(a):
         Debt to Capitalization
         ----------------------

         1. Consolidated Indebtedness*                   $___________

         2. Consolidated Capitalization*                 $___________
         3. Debt to Capitalization Ratio
                  (Line 1 / Line 2)                       _____:_____

         Maximum Allowed:  Line A.3 shall be less than
                    or equal to 0.65 to 1.0

B.       Compliance with Section 7.2(b):
         Interest Coverage Ratio
         -----------------------

         1.       Consolidated EBITDA
                  (See Exhibit A attached hereto)        $___________

2. Consolidated Interest Expense $___________
3. Interest Coverage Ratio (Line 1 / Line 2) _____:_____

Minimum Required: Line B.3 shall be greater than or equal to 3.00 to 1.0


* For purposes of such calculation, the portion of Consolidated Indebtedness attributable to obligations under Material Leases shall be the net present value (using (i) the discount rate (A) set forth in Schedule 6.19 of the Credit Agreement, so long as such Schedule 6.19 specifies the same relevant discount rate as is used in calculating such net present value provided to Moody's and S&P or (B) the discount rate used in calculating such net present value provided to Moody's and S&P or (ii) any such other rate as shall be proposed by the Borrower (and agreed upon by the Required Lenders) of all amounts payable under the Material Leases.

Exhibit A to Schedule 1 to Exhibit 7.2(a)

Calculation Schedule to Compliance Certificate As of __________________

------------------------ ---------- --------- ---------- ---------- ----------
                           Twelve
                           Months    Quarter   Quarter     Quarter   Quarter
Consolidated EBITDA        Ended      Ended     Ended       Ended     Ended
                          --------  --------   --------   --------   --------
------------------------ ---------- --------- ---------- ---------- ----------
Consolidated Net Income
------------------------ ---------- --------- ---------- ---------- ----------
+ Extraordinary Losses
------------------------ ---------- --------- ---------- ---------- ----------
- Extraordinary Gains
------------------------ ---------- --------- ---------- ---------- ----------
+ Consolidated Interest
  Expense
------------------------ ---------- --------- ---------- ---------- ----------
+ Taxes
------------------------ ---------- --------- ---------- ---------- ----------
+ Depreciation
------------------------ ---------- --------- ---------- ---------- ----------
+ Amortization
------------------------ ---------- --------- ---------- ---------- ----------
+ Other Non-Cash Losses
------------------------ ---------- --------- ---------- ---------- ----------
- Other Non-Cash Gains
------------------------ ---------- --------- ---------- ---------- ----------
= Consolidated EBITDA
------------------------ ---------- --------- ---------- ---------- ----------


Exhibit 11.3(b)

FORM OF
ASSIGNMENT AND ASSUMPTION

This Assignment and Assumption (the "Assignment and Assumption") is dated as of the Effective Date set forth below and is entered into by and between ______________ (the "Assignor") and _______________________ (the "Assignee"). Capitalized terms used but not defined herein shall have the meanings given to them in the Credit Agreement identified below (as amended, the "Credit Agreement"), receipt of a copy of which is hereby acknowledged by the Assignee. The Standard Terms and Conditions set forth in Schedule 1 attached hereto (the "Standard Terms and Conditions") are hereby agreed to and incorporated herein by reference and made a part of this Assignment and Assumption as if set forth herein in full.

For an agreed consideration, the Assignor hereby irrevocably sells and assigns to the Assignee, and the Assignee hereby irrevocably purchases and assumes from the Assignor, subject to and in accordance with the Standard Terms and Conditions and the Credit Agreement, as of the Effective Date inserted by the Administrative Agent as contemplated below (a) all of the Assignor's rights and obligations in its capacity as a Lender under the Credit Agreement and any other documents or instruments delivered pursuant thereto to the extent related to the amount and percentage interest identified below of all of such outstanding rights and obligations of the Assignor under the respective facilities identified below (including without limitation any Letters of Credit, guarantees, and swingline loans included in such facilities) and (b) to the extent permitted to be assigned under applicable law, all claims, suits, causes of action and any other right of the Assignor (in its capacity as a Lender) against any Person, whether known or unknown, arising under or in connection with the Credit Agreement, any other documents or instruments delivered pursuant thereto or the loan transactions governed thereby or in any way based on or related to any of the foregoing, including, but not limited to, contract claims, tort claims, malpractice claims, statutory claims and all other claims at law or in equity related to the rights and obligations sold and assigned pursuant to clause (a) above (the rights and obligations sold and assigned pursuant to clauses (a) and (b) above being referred to herein collectively as, the "Assigned Interest"). Such sale and assignment is without recourse to the Assignor and, except as expressly provided in this Assignment and Assumption, without representation or warranty by the Assignor.

1. Assignor: ______________________________

2. Assignee: ______________________________ and is an Affiliate/Approved Fund of _________________

3. Borrower: Public Service Company of New Mexico

4. Administrative Agent: Bank of America, N.A. as the Administrative Agent under the Credit Agreement

5. Credit Agreement: Credit Agreement dated as of December 19, 2002 among Public Service Company of New Mexico, as Borrower, the Lenders party thereto and Bank of America, N.A., as Administrative Agent for the Lenders

6. Assigned Interest:



Aggregate Amount of Amount of Commitment/Loans Percentage Assigned of

Commitment/Loans for all          Assigned             Commitment/Loans
         Lenders
------------------------ -------------------------- ----------------------
$                        $                                    %
------------------------ -------------------------- ----------------------

7. After giving effect to the foregoing assignment, the Assignor and the Assignee shall have the following Commitments, Pro Rata Shares, outstanding Loans and Participation Interests:

----------- ------------ -------------- ----------------- -------------------
            Commitments  Pro Rata Share   Outstanding       Participation
                                           Revolving         Interests in
                                             Loans        Letters of Credit
----------- ------------ -------------- ----------------- -------------------
Assignor
----------- ------------ -------------- ----------------- -------------------
Assignee
----------- ------------ -------------- ----------------- -------------------

8. Trade Date: ______________

Effective Date: _____________ ___, 200__

The terms set forth in this Assignment and Assumption are hereby agreed to:

ASSIGNOR

[NAME OF ASSIGNOR]

By:

Name:
Title:

ASSIGNEE

[NAME OF ASSIGNEE]

By:

Name:
Title:

Consented to and Accepted:

BANK OF AMERICA, N.A.,
as Administrative Agent and L/C Issuer

By:
Name:
Title:

Consented to:

PUBLIC SERVICE COMPANY OF NEW MEXICO

By:
Name:
Title:

Schedule1

TERMS AND CONDITIONS FOR
ASSIGNMENT AND ASSUMPTION

1. Representations and Warranties.

1.1 Assignor. The Assignor (a) represents and warrants that
(i) it is the legal and beneficial owner of the Assigned Interest, (ii) the Assigned Interest is free and clear of any lien, encumbrance or other adverse claim and (iii) it has full power and authority, and has taken all action necessary, to execute and deliver this Assignment and Assumption and to consummate the transactions contemplated hereby; and
(b) assumes no responsibility with respect to (i) any statements, warranties or representations made in or in connection with the Credit Agreement or any other Credit Document, (ii) the execution, legality, validity, enforceability, genuineness, sufficiency or value of the Credit Documents or any collateral thereunder, (iii) the financial condition of the Borrower, any of its Subsidiaries or Affiliates or any other Person obligated in respect of any Credit Document or (iv) the performance or observance by the Borrower, any of its Subsidiaries or Affiliates or any other Person of any of their respective obligations under any Credit Document.

1.2. Assignee. The Assignee (a) represents and warrants that
(i) it has full power and authority, and has taken all action necessary, to execute and deliver this Assignment and Assumption and to consummate the transactions contemplated hereby and to become a Lender under the Credit Agreement, (ii) it meets all requirements of an Eligible Assignee under the Credit Agreement (subject to receipt of such consents as may be required under the Credit Agreement), (iii) from and after the Effective Date, it shall be bound by the provisions of the Credit Agreement as a Lender thereunder and, to the extent of the Assigned Interest, shall have the obligations of a Lender thereunder, (iv) it has received a copy of the Credit Agreement, together with copies of the most recent financial statements delivered pursuant to Section 7.1 thereof, as applicable, and such other documents and information as it has deemed appropriate to make its own credit analysis and decision to enter into this Assignment and Assumption and to purchase the Assigned Interest on the basis of which it has made such analysis and decision independently and without reliance on the Administrative Agent or any other Lender, and (v) if it is a foreign lender, attached to the Assignment and Assumption is any documentation required to be delivered by it pursuant to the terms of the Credit Agreement, duly completed and executed by the Assignee; and
(b) agrees that (i) it will, independently and without reliance on the Administrative Agent, the Assignor or any other Lender, and based on such documents and information as it shall deem appropriate at the time, continue to make its own credit decisions in taking or not taking action under the Credit Documents, and (ii) it will perform in accordance with their terms all of the obligations which by the terms of the Credit Documents are required to be performed by it as a Lender.

2. Payments. From and after the Effective Date, the Administrative Agent shall make all payments in respect of the Assigned Interest (including payments of principal, interest, fees and other amounts) to the Assignor for amounts which have accrued to but excluding the Effective Date and to the Assignee for amounts which have accrued from and after the Effective Date.


3. General Provisions. This Assignment and Assumption shall be binding upon, and inure to the benefit of, the parties hereto and their respective successors and assigns. This Assignment and Assumption may be executed in any number of counterparts, which together shall constitute one instrument. Delivery of an executed counterpart of a signature page of this Assignment and Assumption by telecopy shall be effective as delivery of a manually executed counterpart of this Assignment and Assumption. This Assignment and Assumption shall be governed by, and construed in accordance with, the law of the State of New York.


EXHIBIT 10.75

PNM RESOURCES, INC.

EXECUTIVE SAVINGS PLAN


                                TABLE OF CONTENTS

                                                                          Page

ARTICLE I             DEFINITIONS...........................................1

         1.1.     "Committee"...............................................1

         1.2.     "Benefits Department".....................................1

         1.3.     "Board"...................................................1

         1.4.     "Code"....................................................1

         1.5.     "Company".................................................1

         1.6.     "Company Stock"...........................................2

         1.7.     "Company Stock Fund"......................................2

         1.8.     "Compensation"............................................2

         1.9.     "Distribution Election Form"..............................2

         1.10.    "Investment Fund".........................................2

         1.11.    "MESP"....................................................2

         1.12.    "MESP Employer Contribution"..............................2

         1.13.    "MESP Employer Contribution Account"......................2

         1.14.    "MESP Matching Contribution"..............................2

         1.15.    "Participant".............................................2

         1.16.    "Plan"....................................................2

         1.17.    "Plan Administrator"......................................2

         1.18.    "Plan Year"...............................................2

         1.19.    "Recordkeeper"............................................2

         1.20.    "Supplemental Deferral Account"...........................3

         1.21.    "Supplemental Deferral Agreement".........................3

         1.22.    "Supplemental Deferrals"..................................3

         1.23.    "Supplemental Employer Account"...........................3

         1.24.    "Supplemental Employer Credits"...........................3

         1.25.    "Supplemental Matching Credits"...........................3

         1.26.    "Valuation Date"..........................................3

ARTICLE II            ELIGIBILITY; ADOPTION BY AFFILIATES...................3

         2.1.     The Eligible Class........................................3

         2.2.     Selection of Participants.................................3

         2.3.     Discontinuance of Participation...........................3

         2.4.     Adoption by Affiliates....................................4

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                                TABLE OF CONTENTS
                                  (Continued)
                                                                          Page

ARTICLE III           SUPPLEMENTAL DEFERRALS AND CREDITS....................4

         3.1.     Supplemental Deferral Agreement...........................4

         3.2.     Supplemental Deferrals....................................4

         3.3.     Supplemental Matching and Employer Credits................5

         3.4.     Benefits Not Contingent...................................5

         3.5.     Allocation Among Affiliates...............................5

ARTICLE IV            INVESTMENT OF ACCOUNTS................................5

         4.1.     Adjustment of Accounts....................................5

         4.2.     Investment Direction......................................6

         4.3.     Special Company Stock Fund Provisions.....................7

         4.4.     Compliance with Securities Laws...........................7

ARTICLE V             DISTRIBUTIONS.........................................7

         5.1.     Right to Receive Distribution.............................7

         5.2.     Form of Distribution......................................7

         5.3.     Amount of Distribution....................................8

         5.4.     Limits on Distributions of Company Stock..................9

         5.5.     Timing of Distribution....................................9

         5.6.     Accelerated Withdrawals...................................9

         5.7.     Beneficiary Designation..................................10

         5.8.     Withholding..............................................10

         5.9.     Deductibility............................................10

ARTICLE VI            ADMINISTRATION OF THE PLAN...........................10

         6.1.     Appointment of Committee.................................10

         6.2.     Majority Rule and Delegation of Ministerial Acts.........10

         6.3.     Meetings.................................................11

         6.4.     General Powers and Duties................................11

         6.5.     Claims...................................................12

         6.6.     Appeals..................................................12

         6.7.     Right to Examine Plan Documents and to Submit Materials..13

         6.8.     Relevance................................................14

         6.9.     Decisions Final; Procedures Mandatory....................14

         6.10.    Time For Filing Legal Or Equitable Action................14

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                                TABLE OF CONTENTS
                                  (Continued)

                                                                           Page

ARTICLE VII           AMENDMENT OR TERMINATION..............................14

         7.1.     Amendment or Termination..................................14

         7.2.     Effect of Amendment or Termination........................14

ARTICLE VIII          GENERAL PROVISIONS....................................15

         8.1.     Participant's Rights Unsecured............................15

         8.2.     Funding Upon A Change In Control..........................15

         8.3.     No Guaranty of Benefits...................................15

         8.4.     No Enlargement of Employee Rights.........................15

         8.5.     Spendthrift Provision.....................................15

         8.6.     Applicable Law............................................15

         8.7.     Incapacity of Recipient...................................16

         8.8.     Successors................................................16

         8.9.     Unclaimed Benefit.........................................16

         8.10.    Limitations on Liability..................................16

         8.11.    Headings for Convenience Only.............................16

         8.12.    Severability..............................................16

         8.13.    Conflicts.................................................16

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SECOND RESTATED AND AMENDED

PNM RESOURCES, INC.

EXECUTIVE SAVINGS PLAN

The Public Service Company of New Mexico Executive Savings Plan was originally effective as of July 1, 1998. Most recently, the Plan was amended and restated in its entirety, effective as of November 16, 2001. PNM Resources, Inc. (the "Company" or "PNM") became the parent holding company for Public Service Company of New Mexico as of December 31, 2001. Effective as of November 27, 2002, the Company assumed the sponsorship of the Public Service Company of New Mexico Executive Savings Plan and renamed it as the PNM RESOURCES, INC. EXECUTIVE SAVINGS PLAN (the "Plan"). The Plan is maintained solely for the purpose of permitting certain key employees of the Company and its affiliates who participate in the PNM Resources, Inc. Master Employee Savings Plan (the "MESP") to defer compensation and receive credits under this Plan without reference to the limitations on contributions in the MESP or those imposed by the Internal Revenue Code of 1986, as amended. By this document, the Company amends and restates the Plan in its entirety, effective as of January 1, 2003.

ARTICLE I
DEFINITIONS

When a word or phrase appears in this Plan with the initial letter capitalized, and the word or phrase does not begin a sentence, the word or phrase shall generally be a term defined in this Article I. The following words and phrases used in the Plan with the initial letter capitalized shall have the meanings set forth in this Article I, unless a clearly different meaning is required by the context in which the word or phrase is used:

1.1. "Committee" means the committee appointed pursuant to Section 6.1 to assume certain designated responsibilities in connection with the Plan.

1.2. "Benefits Department" means the organizational unit of the Company with responsibility for administering benefit programs.

1.3. "Board" means the Board of Directors of the Company, or any authorized committee of the Board.

1.4. "Code" means the Internal Revenue Code of 1986, as amended from time to time, and any regulations promulgated thereunder.

1.5. "Company" means PNM Resources, Inc., or any affiliate of the Company that is authorized by the Board of Directors to adopt the Plan and which has adopted the Plan, and, to the extent provided in Section 8.8 below, any successor corporation or other entity resulting from a merger or consolidation into or with the Company or a transfer or sale of substantially all of the assets of the Company. Affiliates that adopted the Plan prior to the assumption of the sponsorship of the Plan by the Company, including Public Service Company of New Mexico, shall continue to participate in the Plan.

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1.6. "Company Stock" means common stock issued by the Company.

1.7. "Company Stock Fund" means the Investment Fund described in Section 4.3.

1.8. "Compensation," for purposes of determining the Supplemental Matching and Employer Credits, means the Participant's base salary and other elements of compensation that are considered under the MESP (as it may be amended from time to time) for purposes of calculating the Participant's MESP Employer and Matching Contributions, respectively. For purposes of determining the amount of a Participant's permissible Supplemental Deferrals, "Compensation" means the Participant's base salary and other elements of compensation that are considered under the MESP (as it may be amended from time to time) for purposes of calculating the Participant's MESP pre-tax contributions.

1.9. "Distribution Election Form" means the election form by which a Participant elects the manner in which his accounts shall be distributed pursuant to Section 5.2(b).

1.10. "Investment Fund" means the hypothetical investment fund or funds established by the Plan Administrator pursuant to Article IV.

1.11. "MESP" means the PNM Resources, Inc. Master Employee Savings Plan established effective January 1, 1975, as it may be amended from time to time.

1.12. "MESP Employer Contribution" means the Employer (Nonelective) Contributions made by the Company for the benefit of a Participant under and in accordance with the terms of the MESP in any Plan Year.

1.13. "MESP Employer Contribution Account" means the Matching Contributions Account and/or the Employer Contributions Account established for a Participant under the MESP.

1.14. "MESP Matching Contribution" means the Matching Contributions made by the Company for the benefit of a Participant under and in accordance with the terms of the MESP in any Plan Year.

1.15. "Participant" means an employee of the Company or any affiliate who has been designated or selected for participation in the Plan pursuant to Section 2.2 and to whom or with respect to whom amounts may be credited under the Plan.

1.16. "Plan" means the PNM Resources, Inc. Executive Savings Plan, as adopted herein.

1.17. "Plan Administrator" means the Company. Any action to be taken by the Plan Administrator may be taken by the Company's senior human resources officer.

1.18. "Plan Year" means the calendar year.

1.19. "Recordkeeper" means the entity selected by the Company to keep Plan records and to adjust accounts pursuant to Section 4.1 of the Plan.

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1.20. "Supplemental Deferral Account" means the account maintained under the Plan to record amounts deferred under Section 3.2 of the Plan.

1.21. "Supplemental Deferral Agreement" means the written deferral agreement described in Section 3.1 that is entered into by a Participant with the Company pursuant to this Plan.

1.22. "Supplemental Deferrals" means the deferrals made by a Participant in accordance with Section 3.2.

1.23. "Supplemental Employer Account" means the account maintained under the Plan to record the amounts credited to a Participant in accordance with Section 3.3.

1.24. "Supplemental Employer Credits" means the Employer Credits allocated to a Participant's Supplemental Employer Account in accordance with Section 3.3.

1.25. "Supplemental Matching Credits" means the Matching Credits allocated to a Participant's Supplemental Employer Account in accordance with Section 3.3.

1.26. "Valuation Date" shall mean each business day of the Plan Year.

ARTICLE II
ELIGIBILITY; ADOPTION BY AFFILIATES

2.1. The Eligible Class. The purpose of the Plan is to provide deferred compensation to a select group of management or highly compensated employees. This group of eligible employees is sometimes referred to as the "top hat group."

2.2. Selection of Participants. Any employees of the Company or an adopting affiliate who are Participants in the Plan on the date of adoption of this amended and restated Plan document will continue as such, subject to the provisions of Section 2.3. Effective January 1, 2002 (or such later date as may be established by the Plan Administrator), any employee who is classified as an "officer" of the Company or an adopting affiliate, shall be a Participant. For this purpose, an "officer" is someone who occupies the position of Vice President or higher. The Plan Administrator, in the exercise of its discretion, and with the concurrence of the Company and/or its Board of Directors, may select as Participants any other employees of the Company or an adopting affiliate who the Plan Administrator concludes, in the exercise of its discretion, are properly included in the top hat group. As noted in Section 2.1, this Plan is intended to provide benefits only to members of the top hat group. The Company has determined that all of the current officers are properly includible in the top hat group.

2.3. Discontinuance of Participation. As a general rule, once an individual is a Participant, he will continue as such for all future Plan Years until his retirement or other termination of employment. The Plan Administrator shall discontinue an individual's participation in the Plan if the Plan Administrator concludes, in the exercise of its discretion, that the individual is no longer properly included in the top hat group. If an individual's participation is discontinued, the individual will no longer be eligible to make deferrals or receive credits under this Plan. The individual will not be entitled to receive

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a distribution, however, until the termination of his employment, unless the Plan Administrator, in the exercise of its discretion, directs that a distribution be made as of an earlier date, in which case the individual's accounts shall be distributed on the same basis as if the individual's employment had been terminated. The Participant's accounts will continue to be adjusted to reflect hypothetical investment earnings or losses in accordance with Section 4.1 until the accounts are distributed.

2.4. Adoption by Affiliates. An employee of an affiliate may not become a Participant in the Plan unless the affiliate has previously adopted the Plan. An affiliate of the Company may adopt this Plan only with the approval of the Board. By adopting this Plan, the affiliate shall be deemed to have agreed to assume the obligations and liabilities imposed upon it by this Plan, agreed to comply with all of the other terms and provisions of this Plan, delegated to the Plan Administrator, the Benefits Department, and the Committee the power and responsibility to administer this Plan with respect to the affiliate's employees, and delegated to the Company the full power to amend or terminate this Plan with respect to the affiliate's employees.

ARTICLE III
SUPPLEMENTAL DEFERRALS AND CREDITS

3.1. Supplemental Deferral Agreement. In order to make Supplemental Deferrals, a Participant must execute a Supplemental Deferral Agreement in the form prescribed by the Benefits Department from time to time. In the Supplemental Deferral Agreement, the Participant shall agree to reduce his Compensation in exchange for a Supplemental Deferral in the same amount. The Supplemental Deferral Agreement shall be delivered to the Benefits Department by the time specified in Section 3.2(b).

3.2. Supplemental Deferrals.

(a) Amount. Any Participant may elect to defer, pursuant to a Supplemental Deferral Agreement, the receipt of all or any portion (designated in whole percentages) of the Compensation otherwise payable to him or her by the Company or an adopting affiliate in any Plan Year. The amount deferred pursuant to this paragraph (a) shall be allocated to the Supplemental Deferral Account maintained for the Participant for such Plan Year.

(b) Timing of Elections. As a general rule, the Supplemental Deferral Agreement shall be signed by the Participant and delivered to the Benefits Department prior to January 1 of the Plan Year in which the Compensation to be deferred is otherwise payable to the Participant. The Supplemental Deferral Agreement will indicate whether it is to be effective for a single Plan Year or will remain in effect until properly changed by the Participant. For the Plan Year in which a Participant first becomes eligible to participate in the Plan, the Participant may elect to make Supplemental Deferrals from Compensation otherwise payable in the future during the then current Plan Year by signing and delivering a Supplemental Deferral Agreement within 30 days after the date on which he or she is notified by the Benefits Department that he or she is eligible to participate. Subject to the following, an election made by a Participant shall be irrevocable with respect to the Plan Year covered by the election. One time per Plan Year, a Participant may modify or revoke the election effective for the

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subsequent calendar quarters of the Plan Year by delivering to the Benefits Department a written instrument prior to the first day of the next calendar quarter of the Plan Year (i.e., April 1, July 1, or October 1) for which such modification or revocation is to be effective. Notwithstanding the foregoing sentence, the elections contained in a Supplemental Deferral Agreement shall be irrevocable for the Plan Year covered by the election for purposes of the election to defer Compensation attributable to annual bonuses, awards, or incentive compensation paid to a Participant.

3.3. Supplemental Matching and Employer Credits. Each Plan Year (or more frequently), the Recordkeeper shall allocate Supplemental Matching and Employer Credits to the Participant's Supplemental Employer Account.

(a) Supplemental Matching Credit. The Supplemental Matching Credit shall be in an amount equal to 75% of the first six percent of Compensation deferred by the Participant to the Plan pursuant to a Supplemental Deferral Agreement.

(b) Supplemental Employer Credit. The Supplemental Employer Credit shall equal (i) the MESP Employer Contribution that would have been made on the Participant's behalf to the MESP for the Plan Year if the contributions were not limited by the Code (including, particularly, the limitations imposed by Sections 401(a)(17) and 415 of the Code), reduced by (ii) the MESP Employer Contributions actually made to the MESP on behalf of the Participant in the Plan Year.

3.4. Benefits Not Contingent. Deferrals and credits for any Participant under this Plan are not increased or decreased to the extent a Participant makes or does not make deferrals under the MESP. The Plan should be interpreted and administered in a manner that is consistent with this Section 3.4.

3.5. Allocation Among Affiliates. Each affiliate that participates in the Plan shall bear the costs and expenses of providing benefits accrued by its employee-Participants during periods while they are employed by that affiliate. Such costs and expenses shall be allocated among the participating affiliates in accordance with (a) agreements entered into between the Company and any participating affiliate, or (b) in the absence of such an agreement, procedures adopted by the Company.

ARTICLE IV
INVESTMENT OF ACCOUNTS

4.1. Adjustment of Accounts. Except as otherwise provided elsewhere in the Plan, as of each Valuation Date, each Participant's accounts will be adjusted to reflect deferrals and credits under Article III and the positive or negative rate of return on the Investment Funds selected by the Participant pursuant to
Section 4.2(b). The rate of return will be determined by the Recordkeeper pursuant to Section 4.2(f) and will be credited or charged in accordance with written policies applied to all Participants. While the accounts will be adjusted as of each Valuation Date, the Recordkeeper shall only post the adjustments as of the last business day of each month.

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4.2. Investment Direction.

(a) Investment Funds. Each Participant may direct the hypothetical investment of amounts credited to his accounts in one or more of the Investment Funds. The Investment Funds shall include a Company Stock Fund and such other investment funds as may be available under the MESP. The Investment Funds may be changed from time to time by the Administration Committee, in its discretion.

(b) Participant Directions. Upon becoming a Participant in the Plan, each Participant may direct that all of the amounts attributable to his accounts be invested in a single Investment Fund or may direct that fractional (percentage) increments of his accounts be invested in such fund or funds as he shall desire in accordance with such procedures as may be established by the Committee. Unless the Committee prescribes otherwise, such procedures shall mirror the procedures established under the MESP for participant investment direction. A Participant's ability to direct investments into or out of the Company Stock Fund shall be subject to such procedures as the Company's General Counsel (or his delegate) may prescribe from time to time to assure compliance with Rule 16b-3 promulgated under Section 16(b) of the Securities Exchange Act of 1934, as amended, and other applicable requirements. Such procedures also may limit or restrict a Participant's ability to make (or modify previously made) elections.

(c) Changes and Intra-Fund Transfers. Participant investment directions may be changed, and amounts may be transferred from one hypothetical Investment Fund to another, in accordance with the procedures established by the Committee (or, in the case of the Company Stock Fund, the General Counsel) pursuant to Section
4.2(b). The designation will continue until changed by the timely submission of a new designation.

(d) Default Selection. In the absence of any designation, a Participant will be deemed to have directed the investment of his accounts in such Investment Funds as the Committee, in its sole and absolute discretion, shall determine.

(e) Impact of Election. The Participant's selection of Investment Funds shall serve only as a measurement of the value of the Participant's accounts pursuant to Section 4.1 and Section 4.2 and neither the Company nor the Committee are required to actually invest a Participant's accounts in accordance with the Participant's selections.

(f) Rate of Return. Accounts shall be adjusted on each Valuation Date to reflect investment gains and losses as if the accounts were invested in the hypothetical Investment Funds selected by the Participants in accordance with
Section 4.2 and charged with any and all reasonable expenses related to the administration of the Plan including, but not limited to, the reasonable expenses of carrying out the hypothetical investment directions related to each account. The earnings and losses determined by the Recordkeeper in good faith and in its discretion pursuant to this Section shall be binding and conclusive on the Participant, the Participant's beneficiary and all parties claiming through them.

(g) Charges. The Committee may direct the Recordkeeper to charge each Participant's accounts for the reasonable expenses of carrying out investment instructions directly related to such accounts.

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4.3. Special Company Stock Fund Provisions.

(a) General. A Participant's interest in the Company Stock Fund shall be expressed in whole and fractional hypothetical units of the Company Stock Fund. As a general matter, the Company Stock Fund shall track an investment in Company Stock in the same manner as the MESP's company stock fund. Accordingly, the value of a unit in the Plan's Company Stock Fund shall be the same as the value of a unit in the MESP's company stock fund.

(b) Dividends and Stock Splits. If a cash dividend is declared on Company Stock, the hypothetical equivalent cash dividends attributable to the notional shares held in the Company Stock Fund shall be "reinvested" into the Company Stock Fund. If a stock dividend or share split is declared with respect to Company Stock, a hypothetical equivalent stock dividend or stock split attributable to the notional shares held in the Company Stock Fund, or any hypothetical securities issued with respect to the Company Stock Fund shall be allocated to the Company Stock Fund. All such hypothetical dividends (cash or stock) or stock splits shall be reflected appropriately in the Participant's accounts.

4.4. Compliance with Securities Laws. Any election by a Participant to hypothetically invest any amount in the Company Stock Fund, and any elections to transfer amounts from or to the Company Stock Fund to or from any other Investment Fund, shall be subject to all applicable securities law requirements, including but not limited to Rule 16b-3 promulgated by the Securities Exchange Commission. To the extent that any election violates any securities law requirement, the election shall be void.

ARTICLE V
DISTRIBUTIONS

5.1. Right to Receive Distribution. Following a Participant's termination of employment for any reason, including death or "Change in Control" (as defined in the Company's Employees' Retirement Plan, or any successor plan), the Participant's interest in this Plan will be distributed to the Participant at the time and in the manner provided in Sections 5.5 and 5.2. A transfer of a Participant from the Company to an affiliate that is authorized by the Board of Directors to adopt the Plan and that has adopted the Plan shall not be deemed a termination and such transfer shall not trigger a distribution of benefits under this Plan.

5.2. Form of Distribution.

(a) Company Stock Fund. Subject to Sections 5.2(c) and 5.4, the portion of a Participant's accounts that is allocated to the Company Stock Fund shall be distributed in a single lump sum payment in whole shares of Company Stock (with fractional shares paid for in cash) unless the Participant elects to receive a cash distribution. The election to receive cash or Company Stock shall be made at the time and in the manner provided in the form prescribed by the Benefits Department from time to time for that purpose. Any election made by a Participant pursuant to this Section with respect to a distribution from the Company Stock Fund shall be subject to all applicable securities law requirements, including but not limited to, Rule 16b-3. Any election that may not be implemented due to the lack of any available exemption shall be void. The

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Benefits Department may then make the distribution in any fashion that will not result in a violation of any applicable securities law requirements. The Benefits Department also may delay the distribution if necessary. An exemption to the securities law requirements that is only available with the prior approval of the Board, the shareholders, or some other individual or individuals, shall not be considered to be available unless such approval is actually granted in a timely manner.

(b) Non-Company Stock Investment Funds. Subject to Section 5.2(c), the portion of a Participant's accounts that is not allocated to the Company Stock Fund shall be distributed in cash in a single lump sum payment, installments, or in the form of an annuity. Installments and annuity distributions shall be subject to such uniform rules and procedures as may be adopted by the Plan Administrator from time to time. The method of payment shall be selected by the Participant in the initial Distribution Election Form (which may be contained in a Supplemental Deferral Agreement) submitted by the Participant to the Benefits Department on entry into the Plan or following the adoption of this amended and restated Plan, whichever is later. A Participant may change his distribution election by filing a new Distribution Election Form with the Benefits Department. A revised Distribution Election Form will be honored only if at least one year elapses between (1) the date on which such new Distribution Election Form is filed with the Benefits Department and (2) the date on which the Participant terminates employment with the Company. If a revised Distribution Election Form is not honored because it was not timely filed, distributions shall be made pursuant to the most recent Distribution Election Form filed by the Participant at least one year prior to the Participant's termination. If no valid Distribution Election Form exists (or if the only valid form was filed within the one year period described above), the Participant's accounts will be distributed in a single lump sum.

(c) Limitations on Distributions and Intra-Fund Transfers. Amounts transferred pursuant to Section 4.2(c) to or from the Company Stock Fund shall, for a one-year period, continue to be subject to the distribution elections applicable to such amounts (as adjusted for earnings or losses) pursuant to Sections 5.2(a) and (b) as if no transfer had taken place. For example, if a Participant transfers $25,000 to the Company Stock Fund from other Investment Funds on January 1, 2002, then that transferred $25,000, as adjusted for subsequent earnings or losses, shall continue to be distributable in cash pursuant to the distribution method elected pursuant to Section 5.2(b) until January 1, 2003. If the Participant had transferred $25,000 from the Company Stuck Fund into the other Investment Funds, then the transferred amount, as adjusted for subsequent earnings or losses, would be distributable in cash in the form of a lump sum pursuant to Section 5.2(a) until January 1, 2003. Only amounts actually invested in the Company Stock Fund, for the requisite one-year period, however, shall be distributable in Company Stock.

5.3. Amount of Distribution. The amount distributed to a Participant shall equal the sum of the amounts credited to the Participant's Supplemental Deferral Account and Supplemental Employer Account as of the quarterly Valuation Date next following the Participant's termination of employment. For purposes of this Plan, a "quarterly Valuation Date" is a Valuation Date that coincides with the last business day of a calendar quarter. Shares of Company Stock that are distributed in cash will be valued at the closing price of the Company Stock on the New York Stock Exchange on the relevant quarterly Valuation Date.

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5.4. Limits on Distributions of Company Stock. Notwithstanding anything to the contrary in this Plan, no individual officer or director of the Company may receive a distribution of Company Stock that exceeds more than one percent of the Company Stock that was outstanding as of the date of the adoption of this amendment and restatement of the Plan. Moreover, all Company Stock issued under this Plan, shall be limited to the amount of Company Stock that may be issued pursuant to Section 312.03(a)(4)(ii) of the New York Stock Exchange Listed Company Manual (generally, considering all Company plans, five percent of the Company Stock outstanding as of the date of the adoption of this amendment and restatement of the Plan).

5.5. Timing of Distribution. Funds will be distributed within an administratively reasonable period of time (generally ten working days) following the applicable quarterly Valuation Date, unless prohibited by the Company's cash position.

5.6. Accelerated Withdrawals. A Participant who is a current employee may elect to receive an accelerated withdrawal of the entire portion of his accounts that is subject to accelerated withdrawal pursuant to Section 5.6(a) by filing a written election with the Benefits Department. Only one accelerated withdrawal may be elected during any 12-month period. Accelerated withdrawals of amounts allocated to the Company Stock Fund may be limited as described in paragraph
(a). Participants who have terminated employment, regardless of whether they have elected or begun receiving installment or annuity payments pursuant to
Section 5.2(b), may not elect to receive an accelerated withdrawal.

(a) Amount of Withdrawal. An accelerated withdrawal pursuant to this
Section 5.6 shall be limited to the lesser of (1) 50% of the value of the Participant's accounts, including any amounts invested in the Company Stock Fund, or (2) the amount that may be charged against the Participant's accounts pursuant to Section 5.6(d). For purposes of determining the amount to be distributed, the Participant's accounts shall be valued as of the effective date of the withdrawal and shall be paid as soon as reasonably possible thereafter.

(b) Forfeiture. A Participant who elects an accelerated withdrawal pursuant to this Section 5.6 shall forfeit an amount equal to 10% of the amount withdrawn as of the day on which the accelerated withdrawal is distributed to the Participant.

(c) Suspension of Participation. Any Participant who elects to receive an accelerated withdrawal pursuant to this Section 5.6 shall be suspended from making Supplemental Deferrals or receiving Supplemental Matching or Employer Credits for 12 months from the date that the accelerated withdrawal is paid to the Participant. Upon expiration of the 12-month suspension period, the Participant shall be permitted to execute a new Supplemental Deferral Agreement pursuant to Section 3.2(b) and to begin making Supplemental Deferrals as of the first day of the first payroll period in any subsequent calendar quarter of the Plan Year.

(d) Allocation of Amount Withdrawn and Forfeiture. The amount withdrawn and any forfeiture will be charged to the Participant's accounts in accordance with such procedures as may be adopted from time to time by the Plan Administrator. Withdrawals from the Company Stock Fund, however, shall be subject to such procedures as the Company's General Counsel (or his delegate) may prescribe from

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time to time to assure compliance with Rule 16b-3 promulgated under Section 16(b) of the Securities Exchange Act of 1934, as amended, and other applicable securities law requirements. If the Participant is unable, pursuant to the preceding sentence, to withdraw amounts invested in the Company Stock Fund, then
(1) no portion of the withdrawal or forfeiture will be charged against the amount allocated to the Company Stock Fund, and (2) the withdrawal and forfeiture shall be limited to the amount of the Participant's accounts that are invested in Investment Funds other than the Company Stock Fund

5.7. Beneficiary Designation. If a Participant should die before receiving a full distribution of his or her Supplemental Deferral and Employer Accounts, distribution shall be made to the beneficiary designated by the Participant. If a Participant has not designated a beneficiary, or if no designated beneficiary is living on the date of distribution, such amounts shall be distributed to those persons entitled to receive distributions of the Participant's accounts under the MESP. The distributions made under this Plan shall be made in a lump sum.

5.8. Withholding. All distributions will be subject to all applicable tax and withholding requirements.

5.9. Deductibility. All amounts distributed from the Plan are intended to be deductible by the Company or the appropriate adopting affiliate. If all or any portion of a distribution will not be deductible, the payment of the nondeductible portion will be postponed until the first year in which it may be deducted. The distribution will be made during the first 60 days of such year. The unpaid amounts will continue to be adjusted pursuant to Article IV until the accounts have been distributed.

ARTICLE VI
ADMINISTRATION OF THE PLAN

6.1. Appointment of Committee. The Company's Benefits Governance Committee, referred to in this Plan as the "Committee," shall have authority to administer the Plan. The Committee shall consist of such members as may be appointed by the Company. The Company may remove any member of the Committee at any time and a member may resign by written notice to the Company. Any vacancy in the membership of the Committee shall be filled by appointment made by the Company, but pending the filling of such vacancy the existing members of the Committee may act hereunder as though they alone constitute the full Committee. The Company may delegate its authority under this Section 6.1 to the Company's Chief Executive Officer.

6.2. Majority Rule and Delegation of Ministerial Acts. Any and all acts and decisions of the Committee shall, if there is more than one member, be by at least a majority of the current members, but the Committee may delegate to any one or more of its members or any other person the authority to sign notices or other documents on its behalf or to perform ministerial acts for it, in which event any other person may accept such notice, document or act without question as having been authorized by the Committee. If the majority of the current members of the Committee are unable to agree to an act or decision, the Committee shall seek instructions from the Company.

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6.3. Meetings. The Committee may, but need not, call or hold formal meetings, and any decisions made or actions taken pursuant to written approval of a majority of the current members shall be sufficient. The Committee shall maintain adequate records of its decisions and those records shall be subject to inspection by the Company. Also, the Committee may designate one of its members as Chairman, and one of its members as Secretary, and may establish policies and procedures governing it so long as the same are not inconsistent with the terms of this Plan.

6.4. General Powers and Duties.

(a) General. The Committee shall perform the duties and exercise the powers and discretion given to it in this Plan document and its decisions and actions shall be final and conclusive as to all persons affected thereby. The Company and the adopting affiliates shall furnish the Committee with all data and information that the Committee may reasonably require in order to perform its functions. The Committee may rely without question upon any such data or information.

(b) Disputes. Any and all disputes that may arise involving Participants or beneficiaries shall be referred to the Committee and its decision shall be final. Furthermore, if any question arises as to the meaning, interpretation or application of any provisions of this Plan, the decision of the Committee shall be final.

(c) Conflicts of Interests. Notwithstanding any other provision of this Plan, during any period in which two or more Committee members are acting, no member of the Committee shall vote or act as a member of the Committee upon any matter involving the member's own rights, benefits or other participation hereunder. If a member of the Committee is recused pursuant to the preceding sentence, then the remaining Committee members may act as if they alone constitute the full Committee.

(d) Agents. The Committee may engage agents, including actuaries, to assist it and may engage legal counsel who may be counsel for the Company. The Committee shall not be responsible for any action taken or omitted to be taken on the advice of such counsel, including written opinions or certificates of any agent, counsel, actuary or physician.

(e) Insurance. At the Committee's request, the Company shall purchase liability insurance to cover the members of the Committee in their activities as the Committee.

(f) Allocations. The Committee is given specific authority to allocate and revoke responsibilities among its members. When the Committee has allocated authority pursuant to this paragraph, the Committee is not to be liable for the acts or omissions of the party to whom such responsibility has been allocated.

(g) Records. The Benefits Department shall supervise the establishment and maintenance of records by the Recordkeeper, the Company and each adopting affiliate containing all relevant data pertaining to any person affected hereby and his or her rights under this Plan. In addition, the Committee may, in its discretion, establish a system for complete or partial electronic administration of the Plan and may replace any written documents described in this Plan with electronic counterparts as it deems appropriate.

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(h) Interpretations. The Committee, in its sole discretion, shall interpret and construe the provisions of the Plan (and any underlying documents or policies).

The foregoing list of powers and duties is not intended to be exhaustive, and the Committee shall, in addition, exercise such other powers and perform such other duties as it may deem advisable in the administration of the Plan, unless such powers or duties are assigned to another pursuant to the provisions of the Plan.

6.5. Claims. The Benefits Department will be responsible for the initial review of all claims. In the event that a Participant or beneficiary (the "claimant") is denied a claim for benefits under this Plan, the Benefits Department shall provide to the claimant written notice of the denial that shall set forth:

(a) The specific reason or reasons for the denial;

(b) Specific references to pertinent Plan provisions on which the Benefits Department based its denial;

(c) A description of any additional material or information needed for the claimant to perfect the claim and an explanation of why the material or information is needed;

(d) A statement that the claimant may:

(i) Request a review by the Committee upon written application to the Benefits Department;

(ii) Review pertinent Plan documents; and

(iii) Submit issues and comments in writing.

(e) An explanation of the Plan's appeal procedures, and an explanation of the time limits applicable to the Plan's appeal procedures, including a statement of the claimant's right to bring a civil action under Section 502(a) of the Employee Retirement Income Security Act of 1974, as amended ("ERISA"). The explanation should also specify that any appeal the claimant wishes to make of the adverse determination must be in writing and must be delivered to the Committee within 60 days after receipt of the Benefits Department notice of denial of benefits. The Benefits Department notice must further advise the claimant that his failure to appeal the action to the Committee in writing within the 60-day period will render the Benefits Department determination final, binding, and conclusive.

6.6. Appeals.

(a) Within 60 days after receiving the written notice of the disposition of the claim described in Section 6.5, the claimant, or the claimant's authorized representative, may appeal such denied claim. The claimant may submit a written statement of his claim (including any written comments, documents, records and other information relating to the claim) and the reasons for granting the claim.

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The Committee shall have the right to request of and receive from the claimant such additional information, documents or other evidence as the Committee may reasonably require. If the claimant does not request an appeal of the denied claim within 60 days after receiving written notice of the disposition of the claim as described in Section 6.5, the claimant shall be deemed to have accepted the disposition of the claim and such written disposition will be final and binding on the claimant and anyone claiming benefits through the claimant, unless the claimant shall have been physically or mentally incapacitated so as to be unable to request review within the 60 day period. The appeal shall take into account all comments, documents, records and other information submitted by the claimant relating to the claim, without regard to whether such documents, records or other information were submitted or considered in the initial benefit determination or the initial review.

(b) A decision on appeal to the Committee shall be rendered in writing by the Committee ordinarily not later than 60 days after the claimant requests review. A written copy of the decision shall be delivered to the claimant. If special circumstances require an extension of the ordinary period, the Committee shall so notify the claimant of the extension with such notice containing an explanation of the special circumstances requiring the extension and the date by which the Committee expects to render a decision. Any such extension shall not extend beyond 60 days after the ordinary period. The period of time within which a benefit determination on review is required to be made shall begin at the time an appeal is filed in accordance with the provisions of paragraph (a) above, without regard to whether all the information necessary to make a decision on appeal accompanies the filing. In the event that a period of time is extended pursuant to this paragraph (b) due to a claimant's failure to submit information necessary to decide a claim, the period for deciding the appeal shall be tolled from the date on which the notification of the extension is sent to the claimant until the date on which the claimant responds to the request for additional information.

If the appeal to the Committee is denied, in whole or in part, the decision on appeal referred to in the first sentence of this paragraph (b) shall set forth:

(i) the specific reason(s) for denial of the claim;

(ii) reference to the specific Plan provisions upon which the denial is based;

(iii) a statement that the claimant is entitled to receive, upon request and free of charge, reasonable access to, and copies of, all documents, records, and other information relevant to the claimant's claim for benefits; and

(iv) a statement of the claimant's right to bring a civil action under
Section 502(a) of ERISA.

6.7. Right to Examine Plan Documents and to Submit Materials. In connection with the determination of a claim, or in connection with review of a denied claim or appeal pursuant to the Plan, the claimant may examine this Plan and any other pertinent documents generally available to Participants relating to the claim and may submit written comments, documents, records and other information relating to the claim for benefits. The claimant also will be provided, upon request and free of charge, reasonable access to, and copies of, all documents, records, and other information relevant to the claimant's claim for benefits with such relevance to be determined in accordance with Section 6.8.

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6.8. Relevance. Documents, records, or other information shall be considered "relevant" to a claimant's claim for benefits if such documents, records or other information:

(a) were relied upon in making the benefit determination;

(b) were submitted, considered, or generated in the course of making the benefit determination, without regard to whether such documents, records or other information were relied upon in making the benefit determination; or

(c) demonstrate compliance with the administrative processes and safeguards required pursuant to this Plan's claims procedures regarding the making of the benefit determination.

6.9. Decisions Final; Procedures Mandatory. To the extent permitted by law, a decision on review or appeal shall be binding and conclusive upon all persons whomsoever. To the extent permitted by law, completion of the claims procedures described in this Plan shall be a mandatory precondition that must be complied with prior to commencement of a legal or equitable action in connection with the Plan by a person claiming rights under the Plan or by another person claiming rights through such a person. The Committee may, in its sole discretion, waive these procedures as a mandatory precondition to such an action.

6.10. Time For Filing Legal Or Equitable Action. Any legal or equitable action filed in connection with the Plan by a person claiming rights under the Plan or by another person claiming rights through such a person must be commenced not later than the earlier of: (1) the shortest applicable statute of limitations provided by law; or (2) two years from the date the written copy of the Committee's decision on review is delivered to the claimant in accordance with
Section 6.6.

ARTICLE VII
AMENDMENT OR TERMINATION

7.1. Amendment or Termination. The Company intends the Plan to be permanent but reserves the right to amend or terminate the Plan when, in the sole discretion of the Company, such amendment or termination is advisable. Any such amendment or termination shall be made pursuant to a resolution of the Board (or its delegate) and shall be effective as of the date of such resolution.

7.2. Effect of Amendment or Termination. Any amendment or termination of this Plan shall apply prospectively only and shall not directly or indirectly reduce the balance of any Plan account as of the effective date of such amendment or termination. Upon termination of the Plan, distribution of amounts in Supplemental Deferral and Supplemental Employer Accounts shall be made to the Participant or his or her beneficiary in the manner and at the time described in Article V of the Plan. No additional credits of Supplemental Deferrals or Supplemental Matching and Employer Credits shall be made to the Supplemental Deferral and Supplemental Employer Accounts of a Participant after termination of the Plan, but the Company may continue to credit or charge gains and losses to the Supplemental Deferral and Supplemental Employer Accounts, until the balance of such Supplemental Deferral and Supplemental Employer Accounts has been fully distributed to the Participant or his or her beneficiary.

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ARTICLE VIII
GENERAL PROVISIONS

8.1. Participant's Rights Unsecured. The Plan at all times shall be entirely unfunded and no provision shall at any time be made with respect to segregating any assets of the Company for payment of any distributions hereunder. The right of a Participant or his or her designated beneficiary to receive a distribution hereunder shall be an unsecured claim against the general assets of the Company, and neither the Participant nor a designated beneficiary shall have any rights in or against any specific assets of the Company. All amounts credited to a Participant's Supplemental Deferral and Supplemental Employer Accounts shall constitute general assets of the Company and may be disposed of by the Company at such time and for such purposes as it may deem appropriate. Nothing in this
Section shall preclude the Company from establishing a "Rabbi Trust", but the assets in the Rabbi Trust must be available to pay the claims of the Company's general creditors in the event of the Company's insolvency.

8.2. Funding Upon A Change In Control. No later than immediately prior to the day on which a "Change in Control" (as defined in the Company's Executive Retention Plan, as it may be amended or replaced from time to time) occurs, the Company shall transfer to the trustee of a "Rabbi Trust" an amount equal to the aggregate value of all Participants' accounts. If it is discovered at any time that the amount initially transferred is less than the total amount called for by the initial sentence of this section, the shortfall shall be transferred to the trustee immediately upon the discovery of such error.

8.3. No Guaranty of Benefits. Nothing contained in the Plan shall constitute a guaranty by the Company or any other person or entity that the assets of the Company will be sufficient to pay any benefit hereunder.

8.4. No Enlargement of Employee Rights. No Participant shall have any right to receive a distribution from the Plan except in accordance with the terms of the Plan. Establishment of the Plan shall not be construed to give any Participant the right to be retained in the service of the Company.

8.5. Spendthrift Provision. No interest of any person or entity in, or right to receive a distribution under, the Plan shall be subject in any manner to sale, transfer, assignment, pledge, attachment, garnishment, or other alienation or encumbrance of any kind; nor shall any such interest or right to receive a distribution be taken, either voluntarily or involuntarily, for the satisfaction of the debts of, or other obligations or claims against, such person or entity, including claims in bankruptcy proceedings. This Section shall not preclude arrangements for the withholding of taxes from deferrals, credits, or benefit payments, arrangements for the recovery of benefit overpayments, arrangements for the transfer of benefit rights to another plan, or arrangements for direct deposit of benefit payments to an account in a bank, savings and loan association or credit union (provided that such arrangement is not part of an arrangement constituting an assignment or alienation).

8.6. Applicable Law. The Plan shall be construed and administered under the laws of the State of New Mexico, except to the extent preempted by the Employee Retirement Income Security Act of 1974, as amended.

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8.7. Incapacity of Recipient. If the Benefits Department is served with a court order holding that a person entitled to a distribution under the Plan is incapable of personally receiving and giving a valid receipt for such distribution, the Benefits Department shall postpone payment until such time as a claim therefor shall have been made by a duly appointed guardian or other legal representative of such person. The Benefits Department is under no obligation to inquire or investigate as to the competency of any person entitled to a distribution. Any payment to an appointed guardian or other legal representative under this Section shall be a payment for the account of the incapacitated person and a complete discharge of any liability of the Company and the Plan therefor.

8.8. Successors. This Plan shall be binding upon the successors and assigns of the Company and upon the heirs, beneficiaries and personal representatives of the individuals who become Participants hereunder.

8.9. Unclaimed Benefit. Each Participant shall keep the Benefits Department informed of his or her current address and the current address of his or her designated beneficiary. The Benefits Department shall not be obligated to search for the whereabouts of any person. If the location of a Participant is not made known to the Benefits Department within three years after the date on which payment of the Participant's Supplemental Deferral and Supplemental Employer Accounts may first be made, payment may be made as though the Participant had died at the end of the three year period. If, within one additional year after such three year period has elapsed, or, within three years after the actual death of a Participant, the designated beneficiary of the Participant has not been located, then there shall be no further obligation to pay any benefit hereunder to such Participant or designated beneficiary and such benefit shall be irrevocably forfeited.

8.10. Limitations on Liability. Notwithstanding any of the preceding provisions of the Plan, neither the Plan Administrator, the Benefits Department or the Committee, nor any individual acting as the Plan Administrator's, the Benefits Department's, the Committee's, or the Company's employee, agent, or representative shall be liable to any Participant, former Participant or other person for any claim, loss, liability or expense incurred in connection with the Plan.

8.11. Headings for Convenience Only. The headings and subheadings of this Plan are inserted for convenience and reference only and are not to be used in construing this instrument or any provision herein.

8.12. Severability. If any provision of this Plan is held to be illegal or invalid, such illegality or invalidity shall not affect the remaining provisions of this Plan, and the remaining provisions shall be construed and enforced as if such illegal or invalid provision had never been inserted herein.

8.13. Conflicts. If any person holds a position under this Plan through which he or she is charged with making a decision about his or her own (or any immediate family member's) Plan participation, including, without limitation, eligibility, account valuation, or investments, then such person shall be recused and the decision shall be made by the Committee.

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IN WITNESS WHEREOF, the Company has caused this Plan to be executed by its duly authorized officer on the date and year first above written.

PNM RESOURCES, INC.

By:      /s/ Jeffry E. Sterba
   ----------------------------------------
         Jeffry E. Sterba
         Chairman, President and CEO

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EXHIBIT 10.86

BEFORE THE NEW MEXICO PUBLIC REGULATION COMMISSION

In the Matter of Public Service Company      )
of New Mexico's                              )
Transition Plan Filed Pursuant to            )           Utility  Case No. 3137
the Electric Utility Industry                )
Restructuring Act of 1999                    )
                                             )
Public Service Company of New Mexico,        )
                                             )
                             Petitioner      )

Stipulated Agreement

The undersigned parties (collectively the "Signatories") have jointly prepared and submit this Stipulated Agreement ("Stipulation") to the New Mexico Public Regulation Commission ("NMPRC" or "Commission") for its approval.

Background and Purpose

1) Public Service Company of New Mexico's ("PNM")1 current New Mexico retail electric base rates were approved by the NMPRC on August 25, 1999, pursuant to a stipulation entered by PNM, NMPRC Staff ("Staff"), the New Mexico Attorney General ("AG"), New Mexico Industrial Energy Consumers ("NMIEC"), City of Albuquerque ("COA"), United States Executive Agencies ("USEA"), and the University of New Mexico ("UNM") in Utility Case No. 2761. Under that stipulation, those rates were not subject to change prior to the earlier of January 1, 2003, or the implementation of customer choice under the New Mexico Electric Utility Industry Restructuring Act of 1999, NMSA 1978, ss.ss. 62-3A-1 et seq. (1999) ("the Restructuring Act").


1"PNM" as used in this Stipulation refers only to the corporate entity known as Public Service Company of New Mexico.

2) In 2001, the New Mexico Legislature adopted changes to the Restructuring Act. Laws 2001, ch. 5, ("Senate Bill 266"). Among other things, Senate Bill 266 postpones the implementation of customer choice under the Restructuring Act until January 1, 2007 for residential and small commercial customers and certain schools, and until July 1, 2007 for all other customers. NMSA 1978, ss. 62-3A-4(A) (2001).
3) Senate Bill 266 further provides for, among other things, New Mexico utilities' activities in respect to generating plants not intended to provide retail electric service to New Mexico customers. The kind of generating plant described in NMSA 1978, ss. 62-3A-8(C) (2001) is referred to here as "Merchant Plant." For purposes of this Stipulation, Merchant Plant also includes transmission, switchyards, or other non-generation facilities required by the transmission provider as a condition to interconnect the generation plant, but no other non-generation facilities. Facilities are no longer Merchant Plant after PNM divests its interest in the plant or the plant receives a certificate of public convenience and necessity pursuant to NMSA 1978, ss.62-9-1 (2001). Palo Verde Nuclear Generating Station Unit 3 ("PVNGS Unit 3") is not "Merchant Plant" under this Stipulation. "Merchant Plant Participation" in this Stipulation shall mean to invest in, acquire, construct or operate specific Merchant Plant by PNM. Merchant Plant Participation does not include issuance of securities by PNM.
4) After passage of Senate Bill 266, the NMPRC initiated an inquiry into issues concerning PNM's plans for Merchant Plant and utility generation resources in Utility Case No. 3137, which is pending.
5) The New Mexico Public Utility Act ("PUA")ss.ss. 62-3-1 et seq. has been repealed effective July 1, 2003. Laws 1998, ch. 108, ss. 82.

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6) The Signatories seek to resolve issues concerning retail electric rates, retail customer choice in New Mexico, PNM's Merchant Plant Participation, energy supply and resources available to retail customers, the pending repeal of the PUA and related matters. Negotiations began in the autumn of 2001 and have culminated in this Stipulation.
7) In consideration of their mutual promises and of the benefits they and their respective constituents will receive, the Signatories, through their undersigned authorized representatives, stipulate and agree as follows:

RETAIL ELECTRIC RATES

8) RATE PATH AND RATE REDUCTIONS: PNM shall reduce current New Mexico jurisdictional retail electric base rates in two phases as shown on Attachment A, except as otherwise provided in this Stipulation. First, PNM shall reduce each element of current New Mexico base rates by 4% effective with service rendered on and after September 1, 2003 ("Phase One Rates"). Next, PNM shall reduce New Mexico base rates from the levels in place at the time this Stipulation is entered by an additional 2.5% effective with service rendered on and after September 1, 2005 ("Phase Two Rates") except as provided in Paragraph 33 (Effect of No Repeal). Provided however, that the Integrated System Streetlighting and Floodlighting Service (PNM Rate Schedule 19), Integrated System Streetlighting and Floodlighting Service - New Installations (PNM Rate Schedule 20) and Private Area Lighting Service (PNM Rate Schedule 6) shall receive a Phase One Rate reduction of 2.5% effective with service rendered on and after September 1, 2003 and through at least December 31, 2007, and no Phase Two Rate reduction, as reflected on Attachment A. The Phase Two rate reduction applicable to Special Contract Service for Large Customers is reflected on Rate 23 in Attachment

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D. The reductions shall not apply to: (a) franchise fee rates or tax rates recovered through a tax adjustment clause authorized by Commission Rule 330, NMAC, 17.1.330, and (b) the Palo Verde refinancing credit approved in NMPRC Case No. 2837. The rates described in this Paragraph 8 (Rate Path and Rate Reductions) shall be referred to here as the "Stipulated Rates." PNM will file an Advice Notice for the Stipulated Rates approved by the NMPRC prior to the effective dates of September 1, 2003 for Phase One Rates and September 1, 2005 for Phase Two Rates, appended to this Stipulation as Attachments H and I, and prior to the effective dates for the other rates approved in this Stipulation.
9) OTHER RATE ISSUES: In PNM's next general rate adjustment proceeding, COA service under PNM Rate Schedules 19 and 20 shall be treated as a separate customer class. A new 70 watt streetlight option shall be added to Rate 20 upon approval of this Stipulation, reflected on Attachment G. 10) RATE CHANGE MORATORIUM: Except as otherwise provided in Paragraph 33 (Effect of No Repeal) and elsewhere in this Stipulation and regardless of changed circumstances, the Phase One Rates shall remain in effect until August 31, 2005 and the Phase Two Rates shall remain in effect until at least December 31, 2007 in accordance with Paragraph 8 (Rate Path and Rate Reductions). The Signatories will not seek to initiate by their own motion or other filing a change in the Stipulated Rates that would take effect prior to January 1, 2008, unless allowed in Paragraph 11 (Rate Change Moratorium Exceptions). The Signatories will not seek prior to September 1, 2006 to initiate by their own motion or other filing a general rate adjustment proceeding to set rates that would take effect upon expiration of the Rate Change Moratorium on December 31, 2007 or thereafter. While final approval of this Stipulation is pending before the NMPRC, the Signatories will not seek to initiate by their own motion or other filing

4

any electric general rate adjustment proceeding, except if the approval is still pending before the NMPRC on April 1, 2003, the Signatories are free to file. If a non-Signatory or the Commission initiates a proceeding to change the Stipulated Rates contrary to these provisions, the Signatories who participate in that proceeding will indicate their support for the provisions of this Stipulation and the continuation of the Stipulated Rates.
11) RATE CHANGE MORATORIUM EXCEPTIONS: The Rate Change Moratorium in this Stipulation shall apply except as follows:
a) PNM may seek a general rate adjustment if the financial impact to PNM during the Rate Change Moratorium in order to comply with new or changed environmental or tax laws or regulations, or a new broader application of existing environmental or tax laws or regulations will compromise PNM's financial integrity during the Rate Change Moratorium. If there is a general rate adjustment under this Paragraph 11(a), the Rate Change Moratorium in Paragraph 10 and the Rate Path and Rate Reductions in Paragraph 8 shall no longer apply.
b) Nothing in this Stipulation shall affect:
i) The continued adjustment of charges for recovery of taxes payable under the Gross Receipts and Compensating Tax Act ("GRCTA") or a substitute or successor tax to the GRCTA as authorized by Commission Rule 330. NMAC 17.1.330;
ii) Charges for franchise fees as a separate line item on bills to customers located within the jurisdiction of the government authority imposing the fee;

5

iii) Recovery of "excess costs" for underground power lines mandated by a local government authority as permitted by the Final Order in NMPRC Case No. 3295 (Rate 22), or as may be modified on remand after appeal.
c) Neither this Stipulation nor changes or deletions in the proposed 4000B tariff shall prejudice, bind or serve as an admission by any Signatory regarding the historic application or availability of PNM's current tariffs to specific customers or regarding the provision of electric generation/transmission to the United States Executive Agencies facilities by the Western Area Power Administration or affect in any way the proceedings in NMPRC Case No. 3135 or FERC Docket No. TX00-1-00, now on appeal to the Tenth Circuit Federal Court of Appeals.
d) PNM may propose to modify tariffs, riders and terms and conditions of rate schedules that do not increase customers' rates or charges. PNM may also propose to implement additional tariffs. The Signatories shall not oppose such proposals on the basis that they involve "piecemeal ratemaking." These proposals are limited to:
i) Economic development or load retention rates requested pursuant to NMSA 1978, ss. 62-6-26 (1999);
ii) New rates for new large customers who do not qualify under existing PNM rate schedules;
iii) Rates for new services not covered in any existing PNM rate schedule or service agreement;
iv) PNM's Uranium Mining/Milling Load Rider applicable to PNM Rate Schedule 4(B), (PNM Rider 7);

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v) Rates for Cogeneration and Small Power Production Facilities under NMPRC Rule 570 (Rate Schedule No. 12);
vi) A tariff for customers voluntarily purchasing renewable energy which PNM may offer in the future pursuant to Paragraph 12 (Renewable Energy Cost Recovery).

12) RENEWABLE ENERGY COST RECOVERY: PNM may seek recovery of the costs of renewable energy resources (either purchased or from owned resources) acquired pursuant to, or used to satisfy, a mandate by any governmental authority only through base rates, and not through any rate rider or adjustment clause. PNM shall be authorized 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 such costs. Each month's capitalized costs shall be considered a separate Regulatory Asset. For Regulatory Assets recorded prior to December 31, 2004, PNM must seek recovery in a general rate adjustment proceeding filed within 54 months of recording a Regulatory Asset, or will be deemed to have waived its right to seek recovery of that Regulatory Asset. For Regulatory Assets recorded after December 31, 2004 but prior to December 31, 2007, PNM must seek recovery in a general rate adjustment proceeding filed within 48 months of recording of a Regulatory Asset, or will be deemed to have waived its right to seek recovery of that Regulatory Asset. For Regulatory Assets recorded after December 31, 2007, PNM must seek recovery in a general rate adjustment proceeding filed within 36 months of recording a Regulatory Asset, or will be deemed to have waived its right to seek recovery of that Regulatory Asset. PNM shall be permitted to recover Regulatory Assets accrued during the pendency of a general rate adjustment proceeding as an outcome of that proceeding. For owned resources required by or used to

7

satisfy such a mandate, all the reasonable costs, including a return on and a return of such capital expenditure, will accrue from the later of the in-service date of the resource or the effective date of the mandate. This Paragraph 12 will remain in effect until at least one year after the conclusion of PNM's second general rate adjustment proceeding filed after December 31, 2007, and thereafter until otherwise ordered by the Commission. PNM retains the right to offer a tariff providing renewable energy resources to customers willing to subscribe voluntarily, and the Signatories agree that the Commission should address any such filing in an expedited proceeding so that a final order may be issued within 60 days from the date of filing. Costs incurred to provide the voluntary renewable energy tariff shall be charged only to the tariff's subscribers. Renewable energy resources acquired pursuant to, or used to satisfy, a government mandate or for the voluntary renewable energy tariff shall be added to PNM's portfolio of included New Mexico jurisdictional generating resources identified in Attachment C, Page 1.
13) SURFACE COAL MINE DECOMMISSIONING COSTS: PNM shall be authorized to recover in these 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 as shown on Attachment B. PNM shall be authorized to recover up to $100 million of the costs shown on Attachment B, composed of approximately $69 million in surface coal mine reclamation costs paid to BHP, Navajo Coal Company and San Juan Coal Company ("Reclamation Costs") and approximately $31 million of contract buyout costs paid to San Juan Coal Company and San Juan Transportation Company ("Contract Buyout Costs"). The costs shall be amortized over 17 years commencing September 1, 2003 and in equal amounts each year after 2004 as shown on Attachment B. PNM will not seek to recover a return on the

8

unamortized Reclamation Costs, but PNM may seek in future rate adjustment proceedings to recover a return on the unamortized Contract Buyout Costs remaining as of December 31, 2007. The Signatories agree not to oppose recovery of the $100 million Reclamation Costs and Contract Buyout Costs shown on Attachment B through retail rates. The recovery of these costs shall only be subject to verification by the Signatories of the amounts actually spent. The Signatories' agreement to allow cost recovery under this paragraph shall not be used as a basis to support PNM's claim for recovery of a return on Contract Buyout Costs after December 31, 2007. Non-PNM Signatories reserve their right to challenge PNM's recovery of a return on Contract Buyout Costs on any basis. PNM shall file verification of the actual amounts spent and the estimate to complete reclamation with the annual filing described in Paragraph 27 (Informational Filings). 14) NUCLEAR DECOMMISSIONING COSTS: The Signatories acknowledge that the Stipulated Rates shall be deemed to provide for full recovery of nuclear decommissioning costs accrued in accordance with the estimates in the most current Decommissioning Cost Study prepared by TLG Services, Inc. during the period the rates are in effect for PNM's interests in PVNGS Units 1 and 2.
15) OFF SYSTEM SALES: The Signatories acknowledge that the Stipulated Rates meet all the requirements of NMSA 1978, ss.62-3A-8(C)(2001) during the period of the Rate Change Moratorium. The risks and benefits of all off-system sales, other than the dollar amounts of those already embedded in the Stipulated Rates, inure solely to PNM's shareholders during the period of the Rate Change Moratorium. To the extent that PNM is permitted by the NMPRC to purchase energy resources from or through a PNM affiliate, the Signatories agree not to argue at the FERC that retail customers are inadequately protected from improper exercise of market power or affiliate abuse during the period of the Rate Change Moratorium.

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16) TRANSITION COSTS: PNM will not seek recovery of transition costs as defined in NMSA 1978, ss. 62-3A-3(CC)(2001) incurred through the date of approval of this Stipulation, including but not limited to all costs characterized as transition costs by PNM in NMPRC Case No. 3137.

GENERATION RESOURCES

17) RESOURCES REQUIRED TO SERVE NEW MEXICO JURISDICTIONAL RETAIL LOAD AND
WHOLESALE FIRM REQUIREMENTS LOAD: Upon approval of the Stipulated Rates by the NMPRC, the portion of San Juan Generating Station Unit 4 previously treated as an excluded resource from PNM's New Mexico retail rates shall be 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 Generation and Transmission Association, Inc., Delta Person Limited Partnership and the 72 MW of firm power from Southwestern Public Service Company shall also now be included as generation resources to serve PNM's New Mexico retail and wholesale firm requirements customers' load until each contract expires. The resulting portfolio of total generation resources consists of PNM's interests in the plants and contracts in the capacity amounts listed on Attachment C, Page 1, as such resources may change pursuant to this Paragraph 17, and Paragraphs 12 and
18 (Renewable Energy Cost Recovery and Resource Additions for Retail Load). PNM's current projected load and resource table is shown as Attachment C, Page 2. The Signatories acknowledge that the generation resources reflected on Attachment C, Page 1, as they may change pursuant to this Paragraph 17, and Paragraphs 12 and 18 (Renewable Energy Cost Recovery and Resource

10

Additions for Retail Load), serve PNM's retail customer and wholesale firm requirements customer loads, and that, consistent with the agreement in Paragraph 15 (Off-system Sales), excess capacity or energy from such resources also may be used for off-system sales. The generation resources on Attachment C, Page 1, as they may change pursuant to this Paragraph 17, and Paragraphs 12 and 18 (Renewable Energy Cost Recovery and Resource Additions for Retail Load), that are used to serve New Mexico retail load and included in New Mexico retail rates are subject to the jurisdiction of the NMPRC and regulation under the PUA. PVNGS Unit 3 shall continue to be treated as excluded plant as described in the Final Orders of the Commission in NMPRC Case Nos. 2146 Part II and 2296. Nothing in this Stipulation shall affect the allocation of fuel costs among the three PVNGS Units approved in NMPRC Case No. 2087, or the allocation of costs to retail and wholesale loads.
18) RESOURCE ADDITIONS FOR RETAIL LOAD: The Signatories agree that PNM should apply to the NMPRC for all necessary regulatory approvals to add New Mexico jurisdictional generation resources in sufficient quantity and at the appropriate time to maintain a total projected system reserve requirement which is the lesser of approximately 15 percent or the applicable planning reserve level established by the Western Electricity Coordinating Council ("WECC"). Provided that PNM can obtain all necessary regulatory approvals to do so, PNM commits to add load-side generation resources to serve New Mexico jurisdictional retail load between the years 2003 through 2007 if it needs additional resources to maintain this reserve requirement. Lordsburg Generating Station ("Lordsburg"), Afton Generating Station ("Afton") and equipment additions including turbines, which can increase PNM's resource portfolio, are eligible to be included as such resources if PNM obtains

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approval for such inclusion in accordance with NMSA 1978, ss.62-9-1 (2001), NMPRC Rule 440 17 NMAC 5.440, or Paragraph 21(c)(iii) as applicable. The projected reserve margin will be calculated by dividing total jurisdictional resources less total jurisdictional peak load by total jurisdictional peak load. For purposes of this calculation, total jurisdictional resources will be the sum of resources shown on Attachment C, Page 1, as they may change pursuant to this Stipulation. For purposes of this calculation, total jurisdictional peak load includes New Mexico jurisdictional single coincident peak load and peak wholesale firm requirements load projected to be coincident with jurisdictional peak load and contracted prior to September 2, 2002. For purposes of this calculation, total jurisdictional resources shall only include renewable resources to the extent such resources provide expected capacity on peak. Projected firm loads and projected resources shall be used in this calculation. The load of customers electing the Special Contract Service for Large Customers described in Paragraph 19 shall not be included in developing PNM's resource or reserve requirement under this Paragraph 18. The Signatories acknowledge the reserve requirement may temporarily deviate from the target level due to unexpected changes in loads or imbalances caused by the magnitude of new resource additions to meet load growth requirements. The Signatories reserve their right to challenge the prudence or used and usefulness of any of PNM's resource additions, but will not challenge the decision to acquire load-side resources as opposed to non-load-side resources. Load-side resources are resources that do not rely primarily on transmission from or through the Four Corners area for delivery to load. The Signatories acknowledge that PNM may in the future also apply to the NMPRC for all necessary regulatory approvals to include Merchant Plant in rate base pursuant to Paragraph 21 (c)(iii) as facilities subject to the jurisdiction of the NMPRC. The Signatories reserve their

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right to oppose the granting of such approvals for including Merchant Plant in rate base. The retail cost limitation set forth in NMSA 1978, ss.62-3A-8(C) (2001) and in Paragraph 21(c)(iv) of this Stipulation do not apply if PNM has no investment in Merchant Plant. The Signatories agree that this interpretation shall apply regardless of whether ss.62-3A-8(C) is recodified or amended.
19) SPECIAL CONTRACT SERVICE FOR LARGE CUSTOMERS: PNM shall implement a new, optional tariff, Special Contract Service for Large Customers (Rate 23). This tariff is attached as Attachment D. The Signatories acknowledge that Special Contract Service for Large Customers is not subject to the cost limitation described at Paragraph 21(c)(iv). For purposes of implementing this tariff, on or before December 31, 2005, and on or before December 31 of each year thereafter, PNM will file with the NMPRC a statement of its growth in retail load between the peak of the prior year and the peak of the current year. Service under the tariff shall begin on July 1, 2005, except as provided in Paragraph 33 (Effect of No Repeal). Rate 23 incorporates the following provisions without which Rate 23 would not be just and reasonable or in the public interest:
a) Rate 23 sets a minimum 1MW load at a single service location to assure that small customers are not exposed to the price risks inherent in the rate, to match load requirements of power suppliers, and to make the rate administrable without unreasonable additional cost.
b) Rate 23 excludes loads which lack predictability and therefore cause load imbalances.
c) Rate 23 limits the total participating load so as not to jeopardize the utility's ability to recover the cost of, including a reasonable return on, generation facilities and other generation resources acquired to serve New Mexico jurisdictional customers, or to cause such costs to be borne by customers taking service under other retail rates.

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d) Rate 23 makes permanent and irrevocable the request for service under that rate once PNM has entered into the initial contract for generation supply, so that PNM is not required to plan for, construct or acquire rate-based generation resources to serve such customers, thereby preventing service under Rate 23 from becoming a financial burden on PNM or other retail customers. The Signatories agree that they shall not at any time propose modifications to Rate 23, except as to the level of the specified rates, if PNM opposes such modifications, and, in any proceeding before the NMPRC in which the Signatories participate, that they shall oppose any modification to Rate 23, except to the level of the specified rates, if proposed by a non-Signatory, and if PNM opposes such modification. This provision does not limit the right of any Signatory to oppose any modification that is proposed by any Signatory or non-Signatory. The Signatories further agree that, to the extent the Commission modifies Rate 23 over the opposition of the Signatories in a manner that would allow customers eligible for Rate 23 to avoid costs already embedded in PNM's cost of service to jurisdictional customers, such costs shall not be considered to be imprudent, inefficient, wasteful, excess or not used and useful and such costs shall be recoverable by PNM under applicable rates established by the Commission. By agreeing to provide Rate 23 to customers eligible under its provisions (Attachment D), PNM does not waive its right to oppose any modifications to Rate 23 on any basis.

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MERCHANT PLANT

20) MERCHANT PLANT PARTICIPATION APPROVAL: NMPRC approval shall be required as provided in this Stipulation for issuance of securities associated with Merchant Plant and for location approval of Merchant Plant under NMSA 1978,
Section 62-9-3 (2001). No NMPRC approval or other authorization from the NMPRC shall be required for PNM's Merchant Plant Participation as long as PNM meets the following conditions:
a) PNM shall not invest more than $1.25 billion in Merchant Plant, which includes its investment in Lordsburg and Afton.
b) PNM shall have an Investment Grade (as hereinafter defined) credit rating on a stand alone basis and on a consolidated basis with PNM Resources as evidenced by Standard & Poor's ("S&P") letter commitment, provided to the Signatories. The letter commitment shall also provide that PNM's Merchant Plant Participation will not cause PNM's credit rating (stand alone or consolidated) to fall below Investment Grade. In the event S&P no longer provides this type of letter commitment as a business practice, PNM may provide the needed letter commitment from Moody's or Fitch. For purposes of this Stipulation, "Investment Grade" means that all PNM's senior debt is rated BBB- or better by S&P or the equivalent level if rated by another agency. The determination date for Investment Grade status ("Determination Date") shall be the date the letter commitment is delivered to the Signatories but:
i) no later than ten (10) days after receipt by PNM; and
ii) no earlier than 360 days and no later than 30 days prior to scheduled ground-breaking if Merchant Plant is being constructed; or

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iii) no earlier than 180 days and no later than 30 days prior to scheduled closing of the transaction if an interest in Merchant Plant is being acquired through purchase or other financial transaction.
c) PNM shall spend at least $60 million per year in gas and electric utility, non-Merchant Plant infrastructure needed to maintain adequate and reliable service unless PNM demonstrates and the PRC determines that a lesser expenditure is better for customers. The utility portion of capital expenditures made by PNM Resources for PNM infrastructure shall be included in meeting this requirement if the costs are for infrastructure items that have historically been provided by PNM. Staff and the Signatories do not waive any rights to challenge the prudence or reasonableness of any specific items of the $60 million in expenditures. 21) MERCHANT PLANT FINANCINGS: PNM shall file an application for NMPRC financing approval prior to issuing securities designated for financing Merchant Plant ("Merchant Plant Financing"), which, except as otherwise provided in Paragraph 33 (Effect of No Repeal), shall be granted on an expedited basis under subparagraph (e) of this Paragraph 21 pursuant to the following terms, conditions and procedure:
a) PNM shall provide a letter commitment by S&P that PNM has a credit rating of Investment Grade and that PNM's credit rating will remain Investment Grade after the financing occurs both on a stand alone basis and on a consolidated basis with PNM Resources. If S&P no longer provides both types of rating commitments as a business practice, then PNM must obtain the missing commitment from either Moody's or Fitch.
b) PNM shall provide an affidavit from a knowledgeable officer of PNM

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(i) designating the securities as a Merchant Plant Financing;
(ii) describing the purposes for which the proceeds of the securities will be used;
(iii) certifying that the aggregate amount of PNM's securities outstanding and proposed to be outstanding will not exceed the fair value of the properties and business of PNM;
(iv) certifying that, as part of the securities issuance, PNM will not create or assume any lien, security interest or other charge or encumbrance on assets included in its New Mexico retail rates as security for any Merchant Plant Financing;
(v) certifying that PNM will maintain a capital structure with no more than 62% debt, including off-balance sheet debt, after the financing;
(vi) certifying that the Merchant Plant is being financed with at least 50 percent new equity. New equity is PNM retained earnings generated after the approval date of this Stipulation, infusions of additional paid-in-capital from PNM Resources, and new PNM equity issuances. Infusions of additional paid in capital to PNM from PNM Resources are not a financing or a securities issuance and do not need prior Commission approval.
c) PNM shall provide an affidavit from a knowledgeable officer of PNM that Merchant Plant has either a Western Electricity Coordinating Council interconnection or a Southwest Power Pool interconnection deliverable to the New Mexico jurisdiction. PNM will provide testimony in support

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of the request for approval of this Stipulation that such interconnections enhance PNM's utility system reliability. The Signatories agree that this affidavit concerning interconnections along with the other benefits specified below demonstrate a direct and nonspeculative utility purpose for a Merchant Plant Financing, and that no proof of those benefits, other than the affidavit, is required. The Signatories agree that other benefits of Merchant Plant to New Mexico retail jurisdictional customers include:
i) To the extent of their availability, these plants can be used as backup for jurisdictional plant;
ii) Merchant Plant enhances the reliability of PNM's system;
iii) PNM may, at its option, apply to the NMPRC for Merchant Plant to become a jurisdictional resource for providing retail electric service to New Mexico customers; if PNM exercises its option and Merchant Plant becomes a New Mexico jurisdictional resource, that Merchant Plant will be included in New Mexico jurisdictional rate base at its depreciated net book value;
iv) Resources acquired by PNM to serve its retail load after January 1, 2001 shall be at a cost of service no higher than the average book cost plus fuel, other operating and maintenance costs and the utility's authorized rate of return on investment of the utility's Merchant Plant constructed or acquired after January 1, 2001 until Merchant Plant is transferred out of PNM.

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d) PNM shall provide an affidavit from a knowledgeable officer of PNM that the forward five-year annual average of Merchant Plant generating capacity uncommitted to power sales agreements will not exceed 25 percent and will not exceed 40 percent in any single year during the forward five years. The calculation of the percentage shall include all of Lordsburg and Afton, as well as the TNMP power sale agreement. The percentage of committed capacity is the peak requirement (MW) of all power sale agreements from Merchant Plants divided by the total rated capacity of all Merchant Plants. The percentage of uncommitted capacity is the difference between the percentage of committed capacity and 100%. Additionally, the forward five-year annual average of Merchant Plant energy uncommitted to power sales agreements (as measured by energy availability commitments) will not exceed 59 percent and Merchant Plant energy uncommitted to power sales agreements (as measured by energy availability commitments) will not exceed 67 percent in any single year during the forward five years, as measured by energy not committed divided by total Merchant Plant kilowatt hours assuming 100% availability. PNM shall also notify the Signatories in writing if and when PNM becomes aware of its inability to make this demonstration.
e) PNM shall file the affidavits and rating agency letter commitments described here with its application. Within ten days of such filing the Utility Staff shall report to the NMPRC that the application either does or does not contain the required information and that PNM either has or has not satisfied the requirements set forth in subparagraphs a) through d) above. If it does contain the required information and PNM

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has satisfied the specified requirements, Staff will indicate its support for, and the other Signatories will support or not oppose, approval of the Merchant Plant Financing application and the NMPRC acting on the application without a hearing and within 30 days of the date of the application. Merchant Plant Financing applications that meet these requirements shall be deemed to satisfy 17 NMAC 1.2.11(A) and PNM shall be granted a variance from the filing requirements of 17 NMAC 1.2.51(B)(1) through (B)(3) and 17 NMAC 1.2.11(B) except that PNM shall serve notice on the Attorney General in accordance with 17 NMAC
1.2.51(B)(1). Staff and the New Mexico Attorney General may oppose such requests for expedited approval and may obtain a hearing with a prima facie showing of a probable material and adverse impact to customer service or rates as a result of the financing. If PNM's request for approval is denied by the NMPRC after hearing, PNM waives its rights to raise in court that the Commission lacks jurisdiction or statutory authority to issue the order denying PNM's request.
f) If PNM cannot meet the criteria in this Stipulation for expedited financing, PNM may nevertheless request NMPRC approval to issue securities for Merchant Plant Financing pursuant to the procedures and legal standards applicable to issuance of securities under Article 6 of the Public Utility Act and under NMPRC rules, as they exist or may be revised in the future. Non-PNM Signatories may oppose such requests. Prior to 2015, non-PNM Signatories may not argue that a utility purpose is not met if the Merchant Plant meets the criteria described in Paragraph 21 (c) (Merchant Plant Financings). If PNM's request for approval is denied by the NMPRC after hearing, PNM waives its rights to raise in court that the Commission lacks jurisdiction or statutory authority to issue the order denying PNM's request.

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22) CREDIT RATING BELOW INVESTMENT GRADE:
a) Reporting: If PNM's credit rating on a stand alone basis falls below Investment Grade as rated by two of S&P, Moody's or Fitch, or if PNM's credit rating on a consolidated basis with PNM Resources falls below Investment Grade by S&P, PNM shall, within 15 business days, file a report with the NMPRC, copied to all Signatories, that includes information on the status of all Merchant Plant Participation, including the following information for each Merchant Plant project: 1) name of project; 2) total estimated cost of project; 3) amount spent to date; 4) percent completed to date; 5) dollar amount needed to complete the project; 6) additional financing needed to complete the project; 7) amount of Merchant Plant capacity and energy contractually committed; and 8) any other information that PNM believes would be relevant. The Signatories agree that this report shall only be provided by PNM to non-PNM Signatories who sign a confidentiality agreement pursuant to a protective order in forms as attached in Attachment E to this Stipulation, which should be issued by the NMPRC as part of the approval of this Stipulation.
b) New Merchant Plant Participation and Financing: If, at the Determination Date, PNM's credit rating on a stand alone basis is rated below Investment Grade by two of S&P, Moody's or Fitch or if PNM's credit on a consolidated basis with PNM Resources is rated below Investment Grade by S&P, PNM shall apply to the NMPRC for approval to

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initiate new Merchant Plant Participation and new Merchant Plant Financing pursuant to Paragraph 21(f). If PNM's request for approval is denied by the NMPRC after hearing, PNM waives its rights to raise in court that the Commission lacks jurisdiction for statutory authority to issue an order denying PNM's request.
c) Ongoing Merchant Plant Development. "Ongoing Merchant Plant Development" is defined to mean the building or purchasing of Merchant Plant for which the Determination Date has passed. If PNM's credit on a stand alone basis is rated below Investment Grade by two of S&P, Moody's or Fitch, or if PNM's credit on a consolidated basis with PNM Resources is rated below Investment Grade by S&P, PNM may provide to the Signatories a rating agency letter commitment from at least one of the agencies that listed PNM below investment grade determining the credit rating impact of PNM's completion of all or a portion of the Ongoing Merchant Plant Development. PNM shall then be authorized to continue Ongoing Merchant Plant Development as proposed to the rating agency as follows:
i) If PNM delivers a rating agency letter commitment demonstrating a High Outcome as shown on the chart in Attachment F and that PNM's credit rating on a stand-alone basis or on a consolidated basis with PNM Resources will return to investment grade, PNM may continue the Ongoing Merchant Plant Development as proposed to the rating agency without Commission approval and without limitation on the amount of expenditure other than that set forth in Paragraph 20(a) (Merchant Plant Participation Approval).

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ii) If PNM delivers a rating agency letter commitment demonstrating a High Outcome as shown on the chart in Attachment F, PNM may spend up to $150 million to continue the Ongoing Merchant Plant Development as proposed to the rating agency and the Signatories agree not to oppose the continuation up to $150 million by filing a petition to stop it or in a proceeding initiated otherwise. PNM may request NMPRC approval to spend more than $150 million, which non-PNM Signatories may oppose.
iii) If PNM delivers a rating agency letter commitment demonstrating a Medium Outcome as shown on the chart in Attachment F, PNM may spend up to $75 million to continue the Ongoing Merchant Plant Development as proposed to the rating agency and the Signatories agree not to oppose the continuation up to $75 million by filing a petition to stop it or in a proceeding initiated otherwise. PNM may request NMPRC approval to spend more than the $75 million, which non-PNM Signatories may oppose.
iv) If PNM delivers a rating agency letter commitment demonstrating a Low Outcome as defined by the chart in Attachment F, PNM must obtain NMPRC approval to continue the Ongoing Merchant Plant Development, which non-PNM Signatories may oppose.

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v) If the Commission denies PNM's request for approval to spend more than the limits set forth above, or to otherwise continue Ongoing Merchant Plant Development as described in this Paragraph 22
(c)(ii) through (iv), PNM waives its rights to raise in court that the Commission lacks jurisdiction or statutory authority to issue the order denying PNM's request.
d) The Signatories who participate in a proceeding on PNM's application for approval for new Merchant Plant Participation or Merchant Plant Financing under Paragraph 22(b) or to continue Ongoing Merchant Plant Development under Paragraph 22(c)(ii) and 22(c)(iii) will support or not oppose expedited consideration of the application so that a Final Order may be issued no later than 90 days from the date of the application.
e) If PNM regains its Investment Grade credit rating so that it has an Investment Grade rating on a stand-alone basis from any two of S&P, Moody's or Fitch and on a consolidated basis with PNM Resources from S&P, the provisions of Paragraphs 20 and 21 of this Stipulation addressing expedited Merchant Plant Participation and Merchant Plant Financings, will again be applicable.

23) TRANSFER OF MERCHANT OR EXCLUDED PLANT:
a) NMPRC approval shall not be required for PNM to transfer its interests or any part thereof in Merchant Plant or PVNGS Unit 3 from time to time to any other legal entity, provided that the following conditions are met: 1) PNM's debt to capital ratio will not exceed 65% after giving effect to the transfer; and 2) PNM provides a letter commitment from

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S&P to the Signatories 30 days before a transfer stating that the plant transfer will not cause PNM's credit rating on a stand-alone basis to fall below Investment Grade at the time of transfer. Notwithstanding the foregoing, NMPRC approval shall be required before PNM accepts any conditions imposed by an agency other than the NMPRC relating to PNM's application to transfer Merchant Plant or associated wholesale power sales agreements as defined in Paragraph 23(d) if the conditions could impair or diminish the NMPRC's jurisdiction or authority to regulate PNM's transmission and distribution service or non-Merchant Plants.
b) PNM further agrees 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 expenditure of $1.25 billion (including Afton and Lordsburg) on Merchant Plant. PNM may seek a variance from the NMPRC 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. Provided, however, that notwithstanding the foregoing deadlines, in no event shall PNM be required to transfer Merchant Plant if it cannot obtain necessary FERC or NMPRC approval. Non-PNM Signatories agree not to petition the Commission to order the transfer of Merchant Plant by PNM before the dates or under different terms and conditions than those set out here. Non-PNM Signatories agree not to support any attempt by a non-Signatory or the NMPRC to force PNM to transfer the Merchant Plant before the dates or under different terms and conditions than those set out here. PNM may voluntarily transfer Merchant Plant at any time prior to 2015

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pursuant to the terms of Paragraph 23(a) (concerning voluntary transfer). PNM does not waive any legal arguments or rights it may have to seek judicial relief from any NMPRC order requiring that it transfer Merchant Plant at a time earlier than that provided for in this Stipulation.
c) Any PNM debt associated with Merchant Plant or PVNGS Unit 3 that is transferred will either be retired or transferred along with the plant. Debt associated with PVNGS Unit 3 is one-third of the debt associated with PVNGS. The debt associated with PVNGS Unit 3 is currently approximately $32 million. In addition, any other PNM financial liabilities that are identifiable to the transferred Merchant Plant or PVNGS Unit 3 will either be satisfied or transferred along with the Merchant Plant or PVNGS Unit 3. Any such transfer of debt or financial liabilities will also include the release of PNM from responsibility for the debt or financial liability.
d) The transfer of Merchant Plant described in this Paragraph shall mean the transfer of the physical assets or PNM's ownership interest in physical assets constituting the Merchant Plant and the wholesale power sales agreements associated with the Merchant Plant. All wholesale power sales agreements entered into by PNM after September 1, 2002, but not those entered into prior to that date and not those associated with PVNGS 3 if it remains owned by PNM, shall be considered agreements associated with Merchant Plant that must be transferred for purposes of this Paragraph. If PNM seeks to transfer utility employees other than employees who are full time Merchant Plant operators to the new Merchant Plant owner, PNM shall notify the non-PNM Signatories of the employees to be transferred 30 days prior to the transfer. If any

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non-PNM Signatory objects within 15 days after notice is given, PNM shall obtain NMPRC approval for the transfer of those employees that were the subject of the objection. In any event, PNM will make a compliance filing at the NMPRC confirming that the notice procedure was followed.
24) LETTER COMMITMENTS GENERALLY: PNM agrees to provide all rating agency letter commitments obtained for purposes of Paragraphs 20, 21, 22 and 23 to the non-PNM Signatories within 10 days of their receipt by PNM. The Signatories agree that the rating agency letter commitments shall only be provided by PNM to non-PNM Signatories who sign a confidentiality agreement pursuant to a protective order in forms as attached to this Stipulation as Attachment E which should be issued by the NMPRC as part of the approval of this Stipulation.
25) DIVIDEND AND CLASS II RESTRICTIONS: The prohibition against PNM paying dividends in any year in excess of net earnings for that year without prior Commission approval contained in the NMPRC's Holding Company Order, (Recommended Decision at 59, June 28 Order at 14, Errata Notice Aug. 28, 2001) ("Dividend Restriction"), shall apply to transfers of Merchant Plant acquired after July 2002. Provided, however, that PNM can rollover under-utilized dividending capacity in any given year after 2002 to any subsequent period until Merchant Plant is completely transferred out of the utility. The Dividend Restriction does not apply to transfer of Afton, Lordsburg or PVNGS Unit 3. The Dividend Restriction shall not apply to PNM equity infused from PNM Resources, which can be transferred out of PNM without restrictions other than the conditions set forth in Paragraph 23(a)

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(concerning voluntary transfer). In addition, to the extent that transfer of Merchant Plant, as limited by Paragraph 23(d), including associated wholesale power sales agreements, or PVNGS Unit 3 by PNM to any PNM affiliate may be a Class II transaction under NMPRC Rule 450 or the Holding Company Order, the Signatories agree that PNM should be granted a variance upon NMPRC approval of this Stipulation from those provisions of the Rule and Order that apply to Class II transactions involving the transfer. If the variance is not granted, the termination provisions of this Stipulation at Paragraph 36 shall be applicable.
26) JOINT DISPATCH:
In the event Merchant Plant or PVNGS Unit 3 is transferred to a PNM affiliate, the question of whether PNM's generation resources and the affiliate's generation resources will be jointly or independently dispatched is at the affiliate's sole discretion until January 1, 2015. The dispatch function shall always reside in the utility and any formation of a dispatch function in the affiliate shall not impair the dispatch capability of the utility in any way. Non-PNM Signatories will support or not oppose PNM's application for any unconditional FERC approvals or authorizations needed to transfer Merchant Plant to an affiliate or to perform joint dispatch. The Signatories agree that PNM should be granted a variance upon approval of this Stipulation from the provisions of the Holding Company Order prohibiting utility employees from routinely providing services to other affiliate corporate entities (Recommended Decision at 60) only to the extent necessary to permit utility employees to engage in joint dispatch. In any NMPRC proceeding to set rates effective after January 1, 2008, the costs and benefits associated with joint dispatch will be equitably shared between customers and shareholders on a prospective basis.

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27) INFORMATIONAL FILINGS: PNM will file at the NMPRC by February 1 of each year a report, certified as true and correct by the Chief Executive Officer or Chief Operating Officer of PNM, containing the following information:
a) Projected Merchant Plant financings for the current calendar year;
b) Identification of Merchant Plants completed or acquired in the past calendar year;
c) Summary of completed Merchant Plant Financings for the past calendar year;
d) S&P actual coverage tests for the past calendar year and pro forma coverage tests for the current calendar year.
e) The requirements concerning system supply planning reports contained in the Order Approving Stipulation in NMPRC Case No. 2567 are amended so that only the following information must be filed as follows:
i) PNM's peak loads (including its most recent approved load forecast);
ii) PNM's reserve margins;
iii) The capital and operating costs of the existing base load capacity;
iv) A plan for supply, bi-annual (every other year);
v) Sources and amount of power available for purchase;
vi) Financial information and assumptions used to develop the plan for supply;
vii) Sensitivity analyses of assumptions and estimates;
viii) Information concerning capabilities and limitations of supply alternatives;
ix) Sensitivity analyses based on projected changes in fuel prices, regulation and competition;
x) The types and degrees of uncertainty regarding the price and availability of fuel.
xi) Coalmine reclamation cost verification and estimates to complete.

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28) APPLICABILITY: Except as otherwise provided in this Stipulation, the terms and conditions in Paragraphs 20 through 28 concerning Merchant Plant shall remain in force and effect until January 1, 2010, regardless of changed circumstances, unless the Commission grants a variance extending the date for transfer of Merchant Plant or if the NMPRC disallows a transfer under Paragraph 23(b), in which case the Merchant Plant terms and conditions shall continue until the date of transfer. The non-PNM Signatories agree not to seek any changes in those terms and conditions and to not support any non-signatory or the NMPRC seeking such a change. Nothing in this Merchant Plant section shall constitute a waiver by any Signatory of any interpretation or application of NMSA 1978 ss. 62-3A-8(C) unless such waiver is explicitly stated. By agreeing to the approval processes and waivers of certain rights on appeal in this Stipulation, the Signatories do not waive their rights to assert any legal position the Signatory considers meritorious if the provisions of the Merchant Plant Section, Paragraphs 20 through 28, of this Stipulation are no longer applicable.

RESTRUCTURING ACT

29) REPEAL OF RESTRUCTURING ACT: The Signatories, including PNM and PNM Resources through their respective officers, agree to actively and aggressively support legislation that repeals and modifies the Restructuring Act as described in this Paragraph 29 upon approval of this Stipulation by the NMPRC. The Signatories will support passage of such legislation in the Year 2003 Session of the New Mexico Legislature and if

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necessary in the Year 2004 Session and beyond until corporate separation occurs under NMSA 1978, ss. 62-3A-8(C) (2001). The Signatories agree that all sections of the Restructuring Act should be repealed except as described in this Stipulation. The Signatories agree that the following language of Section 62-3A-8(C) as modified here should be retained as a provision of the Public Utility Act:

A public utility may invest in, construct, acquire or operate a generating plant that is not intended to provide retail electric service to New Mexico customers, the cost of which is not included in retail rates and which business activities shall not be subject to regulation by the commission pursuant to the Public Utility Act, except as provided by Section 62-9-3 NMSA 1978. Nothing herein shall diminish a public utility's obligation, by the prudent acquisition of resources, to serve its retail load at a cost of service no higher than the average book cost plus fuel, other operating and maintenance costs and the utility's authorized rate of return on investment of the utility's unregulated generation constructed or acquired after January 1, 2001; provided that this provision does not apply to any public utility that does not acquire unregulated generation after January 1, 2001. The commission shall assure that the regulated business is appropriately credited for any off-system sales made from regulated assets. This section only applies to a public utility that began investing in, constructing or acquiring generating plant pursuant to this Section before July 1, 2004. This Section shall continue to apply until the later of January 1, 2015 or the public utility divests its interest in generating plant acquired or constructed under the provisions of this Section or the plant receives a certificate of convenience and necessity in accordance with NMSA 1978 ss.62-9-1.

30) OTHER RETAINED SECTIONS: The Signatories further agree that the Public Utility Act should be amended to retain the following additional portions of the Restructuring Act:
a) Section 62-3A-18 (A) and (B) relating to franchise fees and gross receipts taxes; and
b) The following language from Section 62-3A-8(J) as modified here:

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Public utilities that provide both electricity and natural gas distribution services shall not be required to functionally separate their electric and gas transmission, transportation and distribution operations from each other, and any rule or order to the contrary is void; and provided further that nothing in this section shall prevent a combined gas and electric distribution company from selling the natural gas commodity to customers pursuant to tariffs approved by the Commission.

c) The following language from Section 62-3A-3 (CC) and Section 62-3A-7A as modified herein:
Notwithstanding repeal of the Restructuring Act, unless otherwise waived, a public utility shall be entitled to an opportunity to recover its transition costs. Utilities may retain these transition costs as a regulatory asset on their books pending recovery which must be complete by January 1, 2010. Transition costs shall mean for purposes of this section those prudent, reasonable and unmitigable costs other than stranded costs, not recoverable elsewhere under either federally approved rates or rates approved by the commission, that a public utility would not have incurred but for its compliance with the requirements of the Electric Utility Industry Restructuring Act of 1999 and rules promulgated thereunder relating to the transition to open access, and the prudent cost of severance, early and enhanced retirement benefits, retraining, placement services, unemployment benefits and health care coverage to public utility nonmanagerial employees who are laid off on of before January 1, 2003, that are not otherwise recovered as a stranded salary and benefits cost. Transition costs shall not include costs that the public utility would have incurred notwithstanding the Electric Utility Industry Restructuring Act of 1999.

31) HOLDING COMPANY ORDER: PNM acknowledges that repeal of NMSA 1978 ss.62-3A-8(A) through (I) and (K) (2001) and NMSA 1978 ss.62-3A-4(E) (2001) does not affect the enforceability of the Holding Company Order. 32) RURAL ELECTRIC COOPERATIVES AND MUNICIPALITIES: Nothing in this Stipulation shall affect and the Signatories have no agreement concerning the repeal or modification of the provisions of the Restructuring Act or the Public Utility Act applicable only to rural electric cooperative utilities or municipal utilities.

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33) EFFECT OF NO REPEAL: This Stipulation shall remain in full force and effect whether or not the Restructuring Act is repealed except as provided in this Paragraph 33 as follows:
a) If a law repealing and modifying the Restructuring Act as set forth in Paragraph 29 (Repeal of Restructuring Act) is not enacted by April 15, 2003, PNM shall not invest more than $400 million in Merchant Plant between April 15, 2003 and March 15, 2004, of which no more than $200 million will be PNM debt.
b) If a law repealing and modifying the Restructuring Act as set forth in Paragraph 29 (Repeal of Restructuring Act) is not enacted by March 15, 2004, the following consequences shall occur:
i) Paragraph 21 (Merchant Plant Financings) shall be suspended and shall remain suspended until the repeal and modifications set forth in Paragraph 29 (Repeal of Restructuring Act) occurs. During the suspension period, PNM shall be required to request NMPRC approval to issue securities for Merchant Plant Financings pursuant to the procedures and legal standards applicable to issuance of securities under Article 6 of the Public Utility Act and under NMPRC rules, as they exist or may be revised in the future. Non-PNM Signatories may not argue that a utility purpose is not met if the Merchant plant meets the criteria described in Paragraph 21(c) (Merchant Plant Financings) incorporated here and made applicable in this subparagraph b of Paragraph 33. Infusions

33

of paid-in-capital to PNM from PNM Resources are not a financing or securities issuance and do not need prior Commission approval. If PNM's request for approval is denied after hearing, PNM waives its rights to raise in court that the Commission lacks jurisdiction or statutory authority to issue an order denying PNM's request.
ii) The limits in Paragraph 33(a) shall no longer apply and the $1.25 billion total limit on investment in Merchant Plant in Paragraph 20(a) shall apply.
iii) The Signatories shall jointly petition the NMPRC to delay corporate separation and all of the other dates established in the Restructuring Act by one year pursuant to NMSA 1978, Section 62-3A- 17(D) (2001);
c) If a law repealing and modifying the Restructuring Act as set forth in Paragraph 29 (Repeal of Restructuring Act) is not enacted by April 8, 2005, the following two consequences shall occur:
i) The Phase Two Rates shall become effective one month early, i.e., with service rendered on and after August 1, 2005;
ii) Availability of Special Contract Service for Large Customers under Paragraph 19 shall not commence until six months after the Repeal of the Restructuring Act.
PUBLIC UTILITY ACT

34) REPEAL OF REPEAL: The Signatories agree to actively and aggressively support legislation in the 2003 Legislative Session that repeals the delayed repeal of the PUA, as cited in Paragraph 5 of this Stipulation, upon approval of this Stipulation by the NMPRC.

34

35) AMENDMENTS: Further, the Signatories agree that upon approval of this Stipulation, they will not support in any manner any amendments to the PUA during the 2003 Legislative Session, other than as specifically set forth in Paragraph 32 (Rural Electric Cooperatives and Municipalities) and elsewhere in this Stipulation.

GENERAL PROVISIONS AND FURTHER VARIANCES

36) The Signatories will use their best efforts to obtain expeditious implementation of this Stipulation by the entry of an appropriate final Commission order and will support approval of this Stipulation by the NMPRC by January 1, 2003. This Stipulation assumes the legality and enforceability of the rates and agreements set forth in this Stipulation. Should any rate or agreement set forth in this Stipulation be rejected, modified or directly or indirectly rendered inoperable by Commission or Court decision, any party shall have the right, by filing a notice of withdrawal with the NMPRC within 30 days after the decision, to withdraw from this Stipulation and render this Stipulation of no further force and effect, in which case the Signatories shall attempt in good faith to negotiate an appropriate substitute rate or agreement. If this Stipulation is not approved or is rendered ineffective, the effective date of the Commission's final order, if not stayed or enjoined, in PNM's next general electric rate adjustment proceeding shall be September 1, 2003, provided that the proceeding is initiated by a filing made before June 1, 2003. The effective date shall be applied to service rendered during and after each customer's first full billing cycle after September 1, 2003. To the extent necessary, refunds will be provided through an appropriate billing credit mechanism. Refunds shall commence simultaneously with the change in rates which result from the general rate adjustment proceeding. The Signatories

35

do not waive any rights they may have to obtain judicial relief from the rate adjustment or any aspect of the final order, including relief by stay, injunction, writ or appeal. If the final order is stayed or enjoined, the effective date of any rate reduction required by a non-appealable final order of the Commission in the same proceeding after affirmance or remand shall be September 1, 2003, shall apply retroactively to service rendered during and after each customer's first full billing cycle after September 1, 2003 and refunded through an appropriate credit mechanism.
37) The rate design, rate design method, the allocation of revenue requirements and the allocation method for setting revenue requirements reflected in the Stipulated Rates are the result of various compromises of the positions of the Signatories in this case for settlement purposes only and shall not constitute an admission of any kind or otherwise bind any signatory or establish any precedent or presumption in any other proceeding, including any proceeding required by the Restructuring Act.
38) The Signatories support PNM being granted, to the extent required by law, variances from any rules, regulations or provisions of prior orders necessary to obtain approval of and implement this Stipulation, except that such variances from the Holding Company Order or NMPRC Rule 450 shall only be granted where explicitly stated in this Stipulation. In the event of any conflict between the terms of this Stipulation and the terms of any prior Commission order, the terms of this Stipulation shall control and the terms of the prior order shall be deemed to have been modified only to the extent necessary to conform to the terms of this Stipulation. Variances should specifically be granted to PNM: 1) from the requirements in NMPRC Rule 530 (NMAC 17.9.530) to file Schedules A through R, the requirement to file a transmittal letter, the requirement to request such variance 30 days before the filing of schedules would be made, and except as the requirements of

36

NMPRC Rule 530 are met by the cost of service that will be filed with the testimony in support of the Stipulation; 2) from NMPRC Rule 531 (NMAC 17.9.531) until the effective date of the Final Order in PNM's next general rate adjustment proceeding; 3) in this proceeding only, from the Holding Company Order requirement that PNM shall file "royalty related information" (December 18, 2001 Order at P. A(6)); and 4) in this proceeding only from the Holding Company Order requirement that PNM disclose in any base rate filing each service function not fully staffed internally, but for which PNM relies on an affiliate in whole or in part. (Rec'd Dec'n at 60, citing pp. 55-56 of COA Ex.1).
39) This Stipulation shall not prejudice, bind, or affect any party, or be viewed as an admission, except to the extent necessary to give effect to or enforce the terms of this Stipulation or unless otherwise specifically stated herein. In the event this Stipulation is not approved by the Commission in its entirety, nothing in this Stipulation or negotiations leading up to its execution shall be construed as an admission of a Signatory's position on any issue nor be used or offered into evidence by any Signatory in this or any other proceeding.
40) This Stipulation shall remain in effect until terminated or modified by unanimous consent of the Signatories, except as otherwise provided in this Stipulation. This Stipulation expresses the full intent, understanding and entire agreement of the Signatories concerning the subject matter hereof. 41) This Stipulation shall be binding upon and inure to the benefit of the successors and assigns of the Signatories.
42) Signatories may agree to the terms of this Stipulation through the execution of a separate signature page.

37

43) Approval of this Stipulation shall be entered as a Final Order in the "Merchant Plant" phase of Utility Case 3137, and as a Final Order dismissing the remainder of Utility No. Case 3137.
44) El Paso Electric Company, Southwestern Public Service Company and Texas-New Mexico Power Company are parties to this case but are not Signatories to this Stipulation (herein the "Non-Signatory Utility Parties".) Except for the provisions of this Stipulation addressed to modification of the Restructuring Act with respect to recovery of transition costs, the Non-Signatory Utility Parties have not agreed to the provisions of this Stipulation and will have no affirmative obligations as a result of this Stipulation but the Non-Signatory Utility Parties do not oppose adoption of this Stipulation by the Commission.
45) Nothing contained in this Stipulation shall create any affirmative obligation for the Non-Signatory Utility Parties or create any precedent in other cases involving those Non-Signatory Utility Parties, except as expressly provided in this Stipulation.

38

Respectfully submitted,

         /s/ Joanne Reuter
---------------------------------------------
Public Service Company of New Mexico
Joanne Reuter, Assistant General Counsel




         /s/ Jeff Taylor
---------------------------------------------
New Mexico Attorney General
Jeff Taylor, Esq., Assistant Attorney General




         /s/ Dahl Harris
---------------------------------------------
New Mexico Public Regulation Commission Staff
, Esq., Staff Counsel




         /s/ Steven S. Michel
---------------------------------------------
New Mexico Industrial Energy Consumers
Steven S. Michel, Esq.

Telephonically approved by Nann Houliston, 10/9/02
City of Albuquerque
Nann Houliston, Esq.

39

BEFORE THE NEW MEXICO PUBLIC REGULATION COMMISSION

In the Matter of Public Service Company of New       )
Mexico's Transition Plan Filed Pursuant to the       )
Electric Utility Industry Restructuring Act of 1999  )    Utility Case No. 3137
                                                     )
Public Service Company of New Mexico,                )
                                                     )
                           Petitioner.               )
-----------------------------------------------------)

AMENDMENT TO STIPULATED AGREEMENT

COME NOW the Signatories to the Stipulated Agreement ("Stipulation") filed herein on October 10, 2002 and The Regents of the University of New Mexico ("UNM") and stipulate as follows:

1. UNM and Public Service Company of New Mexico ("PNM") have agreed upon the terms and conditions of a Service Agreement, to become effective with the implementation of Phase One tariffs in September 2003, which includes a form of Interconnection Agreement and Interconnection Requirements and Safety Standards for UNM's planned new Customer-Owned Generation facility, and these agreements constitute additional consideration for UNM's agreement to the Stipulation through this Amendment.

2. By executing this Amendment, UNM joins in and becomes a Signatory to the Stipulation, as amended herein.

3. Pages 4 and 10 of Attachment A to the Stipulation are withdrawn and amended pages 4 and 10 of Attachment A (Exhibit 1 hereto), which modify only the information concerning Schedule 15B, are substituted.


4. Page 6 of Attachment D to the Stipulation is withdrawn and amended page
6 (Exhibit 2 hereto), which modifies only the information concerning Schedule 15B, is substituted.

5. Rate Schedule 15B, included as part of Attachment H (Phase One Tariffs) to the Stipulation, and Rate Schedule 15B, included as part of Attachment I (Phase Two Tariffs) to the Stipulation, are withdrawn and Amended Rate Schedules 15B (Exhibits 3 and 4 hereto) are substituted, respectively.

6. The first two sentences of Paragraph 29 of the Stipulation are amended with the underlined language to read as follows: The Signatories, including PNM and PNM Resources through their respective officers, agree to actively and aggressively support and UNM agrees not to oppose legislation that repeals and modifies the Restructuring Act as described in this Paragraph 29 upon approval of this Stipulation by the NMPRC. The Signatories will support and UNM agrees not to oppose passage of such legislation in the Year 2003 Session of the New Mexico Legislature and if necessary in the Year 2004 Session and beyond until corporate separation occurs under NMSA 1978, ss. 62-3A-8(C) (2001).

7. The first sentence of Paragraph 34 of the Stipulation is amended to read as follows:

The Signatories agree to actively and aggressively support and UNM agrees not to oppose legislation in the 2003 Legislative Session that repeals the delayed repeal of the PUA, as cited in Paragraph 5 of this Stipulation, upon approval of this Stipulation by the NMPRC.

8. Except as modified herein, the Stipulation remains in full force and effect.

9. Agreement to the terms of this Amendment may be indicated by the execution of a separate signature page.

Dated this 18th day of October, 2002

2

Respectfully submitted,

              /s/ Joanne Reuter
--------------------------------------------
Public Service Company of New Mexico
Joanne Reuter, Assistant General Counsel



              /s/ Jeff Taylor
---------------------------------------------
New Mexico Attorney General
Jeff Taylor, Esq., Assistant Attorney General



              /s/ Dahl Harris
---------------------------------------------
New Mexico Public Regulation Commission Staff
Dahl Harris, Esq., Staff Counsel



              /s/ Stephen S. Michel
---------------------------------------------
New Mexico Industrial Energy Consumers
Stephen S. Michel, Esq.



              /s/ Nann Houliston
---------------------------------------------
City of Albuquerque
Nann Houliston, Esq.

NMPRC Case No. 3137
Amendment to Stipulated Agreement

3

              /s/ Julie C. Weaks
---------------------------------------------
The Regents of the University of New Mexico
by: Julie C. Weaks Gutierrez
    Vice President for Business & Finance
    The University of New Mexico

4

NMPRC Case No. 3137
Amendment to Stipulated Agreement


EXHIBIT 10.87

UNUM PROVIDENT

PNM Resources, Inc.

Your Group Long Term Care Plan

Policy No. 574573

Underwritten by Unum Life Insurance Company of America

01-2003


Policy Excerpt:

Unum Life Insurance Company of America
2211 Congress Street
Portland, Maine 04122

This Certificate of Insurance is a part of the entire contract. This certificate is subject to the terms and conditions stated on the attached pages, all of which are part of the Policy. The Policy is intended to be a qualified Long Term Care insurance contract under Section 7702B(b) of the Internal Revenue Code of 1986.

Policy Number 574573

Caution: If you completed an Application for Long Term Care Insurance which included evidence of insurability, the issuance of this long term care insurance certificate was based upon your responses to the questions on your application. A copy of your Application for Long Term Care Insurance was retained by you when you applied. If your answers are incorrect or untrue, Unum may have the right to deny benefits or rescind your coverage. The best time to clear up any questions is now, before a claim arises! If, for any reason, any of your answers are incorrect, contact Unum at this address: Unum Life Insurance Company of America, 2211 Congress Street, Portland, Maine 04122.

o You are entitled to examine a copy of the Policy during regular office hours at the Policyholder's place of business.

o You have a 30 day right to examine this certificate.

If, after examining this certificate, you are not satisfied for any reason, you may withdraw your enrollment in this plan by returning this certificate within 30 days of its delivery to you. The certificate, to be there with a written request for such withdrawal, must be sent to the Policyholder's plan Administrator.

Upon receipt, your insurance will be deemed void from its effective date and any premium contribution(s) paid will be returned.

THIS CERTIFICATE IS NOT A MEDICARE SUPPLEMENT CERTIFICATE. If you are eligible for Medicare, review the guide to health Insurance for people with Medicare available from Unum.

Unum is not representing Medicare, the federal government or any state government.

NOTICE TO BUYER: This certificate may not cover all of the costs associated with long term care incurred by you during the period of coverage. You are advised to review carefully all coverage limitations.

2

Throughout this certificate:

"You" or "your" means an "insured" or "covered" Active Employee and "insured" or "covered" Family Member.

"Unum" or "we" means Unum Life Insurance Company of America, and

"Policyholder" means PNM Resources, Inc. and its and its covered divisions, covered divisions, subsidiaries, and affiliated companies.

/s/ J. Harold Chandler
---------------------------
President

3

SUMMARY OF BENEFITS

                                      Available                         Available
                                      January 1, 2003                   March 1, 2003

                                      Active Employees-                 Family members
                                      At the Employer's expense         At your expense
                                      -------------------------         ---------------

Monthly Benefit Maximum

Long Term Care (LTC) Facility            $4,000                         $4,000 to $6,000 in
-----------------------------                                           $1,000 increments

Assisted Living Facility                 100% of the LTC                100% of the LTC
------------------------                 Facility amount                Facility amount


Professional Home Care Services          100% of the LTC                100% of the LTC
-------------------------------          Facility amount                Facility amount

                                                                                   OR

Total Home Care                                                         100% of the LTC
---------------
                                                                        Facility amount

Uncapped Compound Inflation Protection   5% compounded annually         5% compounded
--------------------------------------                                  annually

Nonforefeiture Benefit                                                  YES
----------------------

Lifetime Maximum                         36X the LTC                    36X the LTC
----------------
Amount                                   Facility amount                Facility amount
------

                                                                                 OR

                                                                        72X the LTC
                                                                        Facility amount

                                                                                  OR

                                                                        Unlimited


Elimination Period                       90 consecutive days            90 consecutive days
------------------

4

                                        Available
                                        March 1, 2003
                                        Active Employees-
                                        At your expense
                                        ---------------

Monthly Benefit Maximum

Long Term Care (LTC) Facility            $1,000 to $2,000
-----------------------------            additional coverage
                                         in $1,000 increments

Total Home Care                          100% of the LTC
---------------                          Facility amount


                           Other Coverage Options

Nonforefeiture Benefit                   YES
----------------------

Lifetime Maximum                         72 the LTC
----------------                         Facility amount
Amount
                                               OR

                                         Unlimited

5

EXHIBIT 10.88

YOUR EMPLOYEE
BENEFIT PLAN

PNM RESOURCES, INC.

LONG TERM DISABILITY

ALL EXECUTIVES

GROUP NUMBER: 34505

EFFECTIVE DATE: JANUARY 1, 2003


Policy excerpt:

Group Policy No.: 34505-G

MetLife(R)

Metropolitan Life Insurance Company
One Madison Avenue, New York, New York 10010-3690

CERTIFICATE OF INSURANCE
for the Employees of

PNM Resources, Inc.
(called the Employer)

This is your Certificate of insurance for long Term Disability Insurance as long as you are insured under This Plan. The Group Policy and this Certificate may be changed or canceled according to the terms, conditions and provisions of the Group Policy. This Certificate describes the benefits under the Plan in effect as of January 1, 2003. Any prior Certificate relating to the coverage set forth herein is void.

MetLife in its discretion has authority to interpret the terms, conditions, and provisions of the entire contract. This includes the Group Policy, Certificate and any Amendments.

The Group policy is delivered in and administered according to the laws of the governing jurisdiction.

Whenever a reference to "you" or "your" is made in this Certificate of Insurance, it means the covered Employee. Reference to "we", "us" or "our" means MetLife. Reference to "This Plan" means that part of the Employer's plan of employee benefits that is insured by Met Life.

/s/ Robert H. Benmosche
--------------------------------------------------
Robert H. Benmosche
Chairman, President and Chief Executive Officer

1

PLAN HIGHLIGHTS

This Plan Highlights section is a summary of your Long Term Disability Benefits and provisions. See the rest of your Certificate for more information.

It is important to read the rest of your Certificate. It describes your benefits as well as any exclusions and limitations that apply to these benefits. Please read it carefully. You should talk with your Employer if you have any questions.

You will notice that some of the terms used in your Certificate begin with capital letters. These terms have special meanings. They are explained in this Certificate.

EMPLOYEE ELIGIBILITY

Eligible Employee: All officers working at least 32 hours each week. However, if you do not have regular work hours you will be an Eligible Employee if you have worked at least an average of 32 hours a week during the preceding 12 calendar months (or during your period of employment if less than 12 months).

Eligibility Waiting Period:

Active Employees on and after January 1, 2003: 6 months of continuous service as an Employee

Eligibility Date: January 1, 2003 or the date you complete the Eligibility Waiting Period, whichever is later.

2

LONG TERM DISABILITY BENEFITS

Monthly Benefit: 66.67% of the first $25,000 of your Predisability Earnings, reduced by Other Income Benefits. Other Income Benefits are described in
Section B. of Long Term Disability Benefits.

Maximum Monthly Benefit: $15,000

Minimum Monthly Benefit: $100. The Minimum Monthly Benefit will not apply if you are in an Overpayment situation or are receiving income from employment.

Elimination Period: 90 days of continuous Disability

Maximum Benefit Duration: The duration shown below:

   Age on Date                      Maximum Benefit
Disability Starts                       Duration
-----------------                       --------

  Less than 60                         To age 65
       60                              60 months
       61                              48 months
       62                              42 months
       63                              36 months
       64                              30 months
       65                              24 months
       66                              21 months
       67                              18 months
       68                              15 months
   69 and over                         12 months

Work Incentive:

Work while Disabled: No offset for employment earnings during the first 24 months after you have satisfied your Elimination period. However, your Monthly Benefit may be reduced if that total income you are receiving (including Rehabilitation Incentive and Family Care Expenses) exceeds 100% of your Predisability Earnings or Indexed Predisability Earnings.

3

Rehabilitation Incentive: Your Monthly Benefit, before reduction for Other Income Benefits, is increased by 10% while participating in an approved Rehabilitation Program.

Family Care Expenses: While participating in an approved Rehabilitation Program, up to $250 per month incurred for Eligible Family Care Expenses for each Eligible Family Member during the first 24 months after you have satisfied the Elimination Period.

Survivors Benefit: A lump sum equal to 3 times the Monthly Benefit before reductions for Other Income Benefits.

LIMITATIONS

Limitation for Pre-existing Conditions: begins 12 months after your Effective Date of coverage.

Limitation For Disabilities Due to Particular Conditions

Limitation for Disability due to (i) Mental or Nervous Disorders or Diseases; or (ii) Neuromusculoskeletal and Soft Tissue Disorder; or
(iii) Chronic Fatigue Syndrome:

24 Monthly Benefits in your lifetime, or the Maximum Benefit Duration, whichever is less. Benefits may be paid beyond 24 months as described in the provision, subject to certain requirements.

Limitation for Drug, Alcohol or Substance Abuse or Dependence:

One period of Disability in your lifetime for up to: 24 Monthly Benefits; your successful completion of an approved rehabilitative program; your ceasing or refusing the participate in a rehabilitative program; or the Maximum Benefit Duration; whichever is less.

CONTRIBUTIONS

Your Long Term Disability Benefits are paid for by your Employer.

4

EXHIBIT 23.1

INDEPENDENT AUDITORS' CONSENT

We consent to the incorporation by reference in Registration Statement Nos. 333-10993 and 333-100186 of PNM Resources, Inc. on Form S-3; Registration Statement Nos. 333-03303, 333-03289, 333-61598, 333-76316, 333-76288, 333-88372 and 333-100184 of PNM Resources, Inc. on Form S-8 of our report dated February 11, 2003, appearing in this Annual Report on Form 10-K of PNM Resources, Inc. for the year ended December 31, 2002.

DELOITTE & TOUCHE LLP

Omaha, Nebraska
March 17, 2003


EXHIBIT 23.2

INDEPENDENT AUDITORS' CONSENT

We consent to the incorporation by reference in Registration Statement No. 333-53367 of Public Service Company of New Mexico on Form S-3 of our report dated February 11, 2003, appearing in this Annual Report on Form 10-K of Public Service Company of New Mexico for the year ended December 31, 2002.

DELOITTE & TOUCHE LLP

Omaha, Nebraska
March 17, 2003


EXHIBIT 99.1

CERTIFICATION PURSUANT TO 18 U.S.C.ss.1350, AS ADOPTED
PURSUANT TOss.906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K for the period ending December 31, 2002, for PNM Resources, Inc. and Public Service Company of New Mexico ("Companies"), as filed with the Securities and Exchange Commission on March 18, 2003, ("Report"), I, Jeffry E. Sterba, Chief Executive Officer of the Companies, certify pursuant to 18 U.S.C. ss.1350, as adopted pursuant to ss. 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Report fully complies with the requirements of ss. 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Companies.

Date:   March 18, 2003                 By:     /s/ Jeffrey E. Sterba
                                               ---------------------------------
                                               Jeffry E. Sterba
                                               Chairman, President and
                                               Chief Executive Officer


EXHIBIT 99.2

CERTIFICATION PURSUANT TO 18 U.S.C.ss.1350, AS ADOPTED
PURSUANT TOss.906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K for the period ending December 31, 2002, for PNM Resources, Inc. and Public Service Company of New Mexico ("Companies"), as filed with the Securities and Exchange Commission on March 18, 2003, ("Report"), I, Max H. Maerki, Chief Financial Officer (through December 31, 2002), certify pursuant to 18 U.S.C. ss.1350, as adopted pursuant to ss. 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Report fully complies with the requirements of ss. 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Companies.

Date:   March 18, 2003                  By:     /s/ Max H. Maerki
                                                --------------------------------
                                                Max H. Maerki
                                                Senior Vice President,
                                                Corporate Strategy and
                                                Development


EXHIBIT 99.3

CERTIFICATION PURSUANT TO 18 U.S.C.ss.1350, AS ADOPTED
PURSUANT TOss.906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Annual Report on Form 10-K for the period ending December 31, 2002, for PNM Resources, Inc. and Public Service Company of New Mexico ("Companies"), as filed with the Securities and Exchange Commission on March 18, 2003, ("Report"), I, John R. Loyack, Chief Financial Officer (beginning January 1, 2003) of the Companies, certify pursuant to 18 U.S.C. ss.1350, as adopted pursuant to ss. 906 of the Sarbanes-Oxley Act of 2002, that:

(1) the Report fully complies with the requirements of ss. 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) the information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Companies.

Date:   March 18, 2003                 By:     /s/ John R. Loyack
                                               ---------------------------------
                                               John R. Loyack
                                               Senior Vice President and
                                               Chief Financial Officer