As filed with the Securities and Exchange Commission on~~November 26,~~December 8, 2003

(Address, including zip code, and telephone number, including area code, of registrant’s principal executive offices)

Approximate date of commencement of proposed sale to the public: As soon as practicable after the effective date of this Registration Statement.

If the securities being registered on this form are being offered in connection with the formation of a holding company and there is compliance with General Instruction G, check the following box. ¨

If this form is filed to register additional securities for an offering pursuant to Rule 462(b) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ¨

If this Form is a post-effective amendment filed pursuant to Rule 462(d) under the Securities Act, check the following box and list the Securities Act registration statement number of the earlier effective registration statement for the same offering. ¨

We hereby amend this registration statement on such date or dates as may be necessary to delay its effective date until we shall file a further amendment which specifically states that this registration statement shall thereafter become effective in accordance with Section 8(a) of the Securities Act of 1933, as amended, or until this registration statement becomes effective on such date as the Commission, acting pursuant to said Section 8(a), may determine.

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The information in this prospectus is not complete and may be changed. We may not sell these securities until the registration statement filed with the Securities and Exchange Commission relating to these securities is effective. This prospectus is not an offer to sell these securities and it is not soliciting an offer to buy these securities in any state where the offer or sale is not permitted.

We will issue up to $250,000,000 aggregate principal amount of 6.125% Senior Notes due 2008 (the “exchange notes”) in exchange for all of our outstanding 6.125% Senior Notes due 2008 (the “existing notes”) that are validly tendered and not withdrawn prior to the expiration of the exchange offer.

The exchange offer expires at 5:00 p.m., New York City time, on , 2003, unless extended.

Tenders of existing notes may be withdrawn at any time prior to the expiration of the exchange offer.

The exchange of existing notes for exchange notes will not be a taxable event for U.S. federal income tax purposes for most holders. You should read the section entitled “Certain U.S. Federal Income Tax Considerations” for more information.

We do not intend to apply for listing of the exchange notes on any securities exchange or to arrange for the exchange notes to be quoted on any quotation system. There is currently no public market for the exchange notes.

Terms: The terms of the exchange notes are substantially identical to the terms of the existing notes, except that exchange notes have been registered under the Securities Act of 1933 and the transfer restrictions and registration rights relating to the existing notes will not apply to the exchange notes. See “The Exchange Offer—Reasons for the Exchange Offer.”

Maturity Date: June 1, 2008.

Interest Rate: 6.125% per year, payable on May 1 and November 1 of each year, commencing November 1, 2003.

Ranking: The exchange notes will be our senior unsecured obligations and will rank equally in right of payment to our existing unsecured indebtedness, consisting of $175 million 6.25% Senior Notes due 2009, and any future senior unsecured indebtedness. The exchange notes will be subordinated to any future indebtedness (including guaranteed obligations) of our subsidiaries.

Redemption: We may redeem the exchange notes, in whole or in part, any time prior to May 1, 2005, by paying the redemption price described as the “Make Whole Price” in “Description of Senior Notes – Redemption of the Senior Notes Prior to May 1, 2005.” On or after May 1, 2005, we may redeem the exchange notes, at our option, by paying the redemption price described as the “applicable redemption price” in “Description of the Senior Notes – Redemption of the Senior Notes After May 1, 2005.” In addition, on or after May 1, 2005, we will be required to redeem the exchange notes upon the receipt of proceeds of the stranded cost securitization at the applicable redemption price, as described in “Description of the Senior Notes – Redemption of the Senior Notes After May 1, 2005.”

Please read “Risk Factors” beginning on page 11 for a discussion of risk factors you should consider before participating in the exchange offer.

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved of these securities or passed upon the adequacy or accuracy of this prospectus. Any representation to the contrary is a criminal offense.

Each broker-dealer that receives exchange notes for its own account pursuant to the exchange offer must acknowledge that it will deliver a prospectus in connection with any resale of exchange notes. The letter of transmittal states that by so acknowledging and by delivering a prospectus, a broker-dealer will not be deemed to admit that it is an “underwriter” within the meaning of the Securities Act of 1933, as amended. A broker-dealer may use this prospectus, as it may be amended or supplemented from time to time, in connection with resales of exchange notes received in exchange for existing notes where the broker-dealer acquired the existing notes as a result of market-making or other trading activities. We have agreed that, for a period of 180 days after the expiration date, we will make this prospectus available to any broker-dealer for use in connection with any such resale. See “Plan of Distribution.”

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We (also referred to as “TNMP” ) are a regulated utility operating in Texas and New Mexico. In Texas, we are a regulated utility engaged solely in the transmission and distribution of electricity. In New Mexico, we provide integrated electricity services under traditional cost of service regulation. Those services include transmitting, distributing, purchasing and selling electricity to our New Mexico customers. Traditional cost-of-service regulation is a method of regulation that sets rates that we can charge to our electricity customers based upon our cost of providing that service. The cost of providing that service includes a return on the capital we have invested and dedicated to providing electric service. See “Business.”

We and First Choice Power, Inc. (“First Choice”) are wholly owned subsidiaries of TNP Enterprises, Inc., a Texas corporation (“TNP Enterprises” or “TNP”) a holding company that transacts business through its subsidiaries. We have two subsidiaries, Texas Generating Company, L.P. (“TGC”), a Texas limited partnership, and Texas Company II, LLC (“TGC II”), a Texas limited liability company). We formed TGC and TGCII to finance construction of TNP One, our sole generation facility. Until May 2001, we owned TNP One together with TGC and TGC II. At that time, we consolidated the ownership of TNP One into TGC to comply with the Texas Electric Choice Act (the “1999 Restructuring Legislation”).

Effective January 1, 2002, the 1999 Restructuring Legislation established retail competition in the Texas electricity market. Prior to January 1, 2002, we operated as an integrated electric utility in Texas, generating, transmitting and distributing electricity to customers in our Texas service territory. As required by the 1999 Restructuring Legislation, and in accordance with a plan approved by the Public Utility Commission of Texas (the “PUCT”), we separated our Texas utility operations into three components:

No payments or other consideration were exchanged between us, First Choice or TGC in connection with the separation.

We provide First Choice and TNP Enterprises with corporate support services, including accounting, finance, information services, legal and human resources, under a shared services agreement with First Choice dated March 1, 2001 and a similar agreement with TNP Enterprises dated June 6, 1997. These services are billed at our cost and, in return, TNP Enterprises and First Choice compensate us for the use of the services. These arrangements are discussed in Note 10 to the consolidated financial statements dated December 31, 2002, and Note 6 to the consolidated interim financial statements, both of which are included in this prospectus. You may find more information regarding the separation of our Texas operations due to the beginning of retail competition in the “Business” section and in Note 2 to the consolidated financial statements dated December 31, 2002, both of which are included in this prospectus. ^

In June 2003, we asked the New Mexico Public Regulation Commission (“NMPRC”) for permission to form a new wholly-owned subsidiary in 2003 to acquire and hold our New Mexico properties and to conduct our New Mexico operations, which accounted for approximately 16% of our assets at September 30, 2003, and

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approximately 18% of our net income for the twelve months ended September 30, 2003. The purpose of the new subsidiary was to disengage our customers in each state from the risks associated with the other, and to provide us with the flexibility to respond to the competitive aspects of the deregulated retail electricity market in Texas while eliminating any unnecessary risks to our New Mexico customers. In October 2003, we withdrew the request in connection with the approval of our request to guarantee certain power supply obligations of First Choice. You may find more information about this request in Note 2 to the consolidated interim financial statements.

TNP Enterprises had consolidated income applicable to common stock of $5.0 million for the quarter ended September 30, 2003, which represents a $13.5 million decrease when compared with income of $18.5 million for the same period in 2002. The decrease was driven by a decrease in First Choice earnings. First Choice had net income of $6.5 million for the quarter ended September 30, 2003, compared with net income of $17.7 million for the corresponding period in 2002. First Choice is our largest customer. You should read the discussion of risks related to the operations of First Choice and other retail electric providers that are our customers that is included in the “Risk Factors” section of this prospectus.

Our executive offices are located at 4100 International Plaza, Fort Worth, Texas 76109, and our telephone number is (817) 731-0099.

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On June 10, 2003, we sold the existing notes in a private offering to Barclays Capital Inc. and CIBC World Markets Corp., collectively referred to as the initial purchasers. As part of the private offering, we entered into a registration rights agreement with the initial purchasers in which we agreed, among other things, to deliver this prospectus to you and to use our reasonable best efforts to complete the exchange offer on or before December 7, 2003. The following is a summary of the material terms of the exchange offer.

the exchange offer, or the making of any exchange by a holder of existing notes would violate applicable law or any applicable interpretation of the SEC staff;

an action or proceeding has been instituted or threatened in a court or before a government agency or body with respect to the exchange offer;

a law, statute or regulation that can reasonably be expected to impair our ability to proceed with the exchange offer has been adopted or enacted;

a holder has not made to us the representations described in “The Exchange Offer—Your Representations to Us” and any other representations as may be reasonably necessary under applicable SEC rules, regulations or interpretations to allow us to use an appropriate form to register the exchange notes under the Securities Act; or

a stop order has been threatened or is in effect with respect to the registration statement of which this prospectus is a part or the qualification of the indenture relating to the notes under the Trust Indenture Act of 1939.

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extend the exchange offer;

terminate the exchange offer; or

amend the terms of the exchange offer.

DTC has received your instructions to transfer your existing notes;

you agree to be bound by the terms of the letter of transmittal; and

we may enforce such agreement against you.

a book entry confirmation of such existing notes into the exchange agent’s account at DTC; and

a properly transmitted agent’s message.

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agreement. See “The Exchange Offer—Shelf Registration Statement.” In addition, you will not be able to resell, offer to resell or otherwise transfer the existing notes unless we have registered the existing notes under the Securities Act, or unless you resell, offer to resell or otherwise transfer them under an exemption from the registration requirements of, or in a transaction not subject to, the Securities Act.

you acquire the exchange notes other than in the ordinary course of your business;

you are participating, intend to participate or have an arrangement with any person to participate, in a distribution of the exchange notes;

you are our “affiliate,” as defined in Rule 405 under the Securities Act; or

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you are a broker-dealer that acquired existing notes directly from us.

you will not be able to rely on the interpretations of the staff of the SEC in connection with any offer for resale, resale or other transfer of the exchange notes; and

you must comply with the registration and prospectus delivery requirements of the Securities Act, or have an exemption available, in connection with any offer for resale, resale or other transfer of the exchange notes.

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The exchange notes will be identical in all material respects to the existing notes except that the offering of the exchange notes has been registered under the Securities Act and the transfer restrictions and registration rights relating to the existing notes will not apply to the exchange notes. The exchange notes will evidence the same debt as the existing notes, and the same indenture will govern the exchange notes and the existing notes.

The following summary contains basic information about the exchange notes and is not intended to be complete. It does not contain all the information that is important to you. For a more complete understanding of the exchange notes, please refer to the section of this prospectus entitled “Description of the Senior Notes.”

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punctually pay the principal and interest on the exchange notes;

maintain an office or agency in each place where the exchange notes may be presented or surrendered for payment, transfer or exchange;

deposit funds to pay principal and interest for the exchange notes in trust or with a paying agent;

deliver annual reports of our compliance with the indenture to the trustee;

maintain our corporate existence, properties used in the conduct of our business, and insurance;

comply with applicable laws; and

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we fail to file the exchange offer registration statement or any required shelf registration statement within the time period prescribed by the registration rights agreement;

the exchange offer registration statement or any required shelf registration statement that we file is not declared effective within the time period prescribed by the registration rights agreement; or

(i) we do not consummate the exchange offer within the time period prescribed by the registration rights agreement; or (ii) the exchange offer registration

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You should carefully consider the risks described below as well as other information contained in this prospectus before tendering your existing notes for exchange in the exchange offer. These risks are those currently known to us and unique to our company or industry in Texas that we consider to be material to your decision to tender your existing notes for exchange in the exchange offer. If any of the following risks occur, our business, financial condition or results of operations could be materially harmed which could result in a loss or a decrease in the value of your investment.

Any delay or default in payment from one or more retail electric providers through which we provide transmission and distribution services could adversely affect the timing and receipt of our cash flows, thereby having an adverse effect on our ability to pay our cash obligations when due, including cash payments on the existing notes and the exchange notes.

In Texas we provide transmission and distribution services through various retail electric providers (“REPs”) that, in turn, provide retail electric service within our Texas service area. Currently, we do business with approximately 24 REPs. Our revenues in Texas were approximately $156.1 million for the year ended December 31, 2002 and accounted for approximately 51% of our total revenues. First Choice accounts for approximately 69% of our anticipated 2003 revenues from REPs. Adverse economic conditions (such as high unemployment, a depressed or recessionary economy and high interest rates), structural problems in the newly deregulated Texas electricity market (such as difficulties encountered in the information flow between the various market participants) or financial difficulties of one or more REPs resulting from a distressed or bankruptcy situation could impair the ability of these REPs to pay for our services or could cause them to delay such payments. We depend on these REPs for timely remittance of payments. Any delay or default in payment, particularly by First Choice, could adversely affect the timing and receipt of our cash flows and cash reserves, thereby decreasing our ability to pay our cash obligations when due, including cash payments on the existing notes and the exchange notes.

We have guaranteed First Choice’s performance under a power supply contract. If we are required to perform First Choice’s obligations under the power supply contract in the event of First Choice’s default thereunder, our costs will increase, thereby reducing our ability to pay our cash obligations, including cash payments on the exchange notes.

We have guaranteed First Choice’s performance under a power supply contract with Constellation Power Source, Inc. (“Constellation”) for up to $50 million. Our guarantee requires us to assume the obligations of First Choice in an event of default by First Choice under that agreement. If we are required to perform First Choice’s obligations under the power supply contract pursuant to our guarantee, our costs will increase, thereby reducing our ability to pay our cash obligations, including cash payments on the exchange notes.

Our business is seasonal and extended periods of weather that is cooler than normal will decrease the demand for electricity, thereby diminishing the amount of electricity we distribute on behalf of each REP and the amount of revenues we collect from those REPs.

Our revenue in Texas is derived from rates that we collect from each REP based on the amount of electricity we distribute on behalf of each REP. In New Mexico, our revenue is from integrated electricity services we provide. Our business in Texas and New Mexico is generally seasonal. In both our Texas and New Mexico service areas, demand for power peaks during the hot summer months. We have historically sold less power, and consequently earned less income, when weather conditions are milder. Extended periods of weather that is cooler than normal in the future will decrease the demand for electricity, thereby diminishing the amount of electricity we distribute on behalf of each REP and the amount of revenues we collect from those REPs.

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Interruptions in service caused by breakdowns of equipment, weather related events, accidents or catastrophic events, or the inability to complete improvements to our transmission and distribution system could adversely affect our revenues and increase our expenses. As we maintain, expand, and upgrade our transmission and delivery systems, circumstances beyond our control could cause maintenance and capital expenditures to increase. These factors could reduce our ability to pay our cash obligations, including cash payments on the exchange notes.

Breakdowns or failures of the equipment or facilities used in our transmission and delivery systems could interrupt energy delivery services and related revenues, and increase repair expenses and capital expenditures. Prolonged or repeated failure of equipment or facilities, whether due to age, accidents, defective equipment, or weather related incidents (such as tornadoes or hurricanes) or accidents could affect customer satisfaction and result in increased regulatory oversight and increased levels of maintenance and capital expenditures. Equipment outages and repair costs due to catastrophic events, such as storms, natural disasters, wars or terrorist acts (to the extent not covered by insurance) would adversely affect our revenues, operating and capital expenses, thereby reducing our ability to pay our cash obligations, including cash payments on the exchange notes.

Our ability to successfully and timely complete capital improvements to existing facilities or other capital projects is contingent upon many variables, including access to adequate funding, weather, availability of replacement equipment and availability of qualified engineering and repair personnel. It is also subject to substantial risks if problems arise with any of these variables. Should any such capital projects be unsuccessful, we could be subject to additional costs and/or the write off of our investment in the project or improvement.

We are subject to merger commitments that may cause costs of operations to increase thereby reducing cash reserves and decreasing our ability to make payments on the exchange notes.

As conditions for approval of the acquisition in April 2000 of our parent, TNP Enterprises, by ST Acquisition Corp. (the “Merger”), TNP Enterprises and we made a number of commitments to both the PUCT and the NMPRC. The commitments cover a wide range of financial, operational, electric reliability, and other standards that we agreed to honor. We made 55 commitments in New Mexico and Texas, of which 47 are currently in effect. These commitments include minimum annual requirements for maintenance and capital expenditures, employee safety and customer service staffing levels, electric reliability standards regarding the duration and frequency of outages, numerous reporting requirements and we must strive to maintain investment grade credit ratings. We monitor compliance on a monthly basis and could be subject to financial penalties for non-compliance with certain commitments. During the years ended December 31, 2002 and 2001, we were not in compliance with one commitment regarding electric reliability standards in Texas, and as a result paid $0.2 million in penalties during the second quarter of 2003. The commitments may affect our operations and further penalties may be incurred in the future. If expenditures required to comply with our merger commitments were to increase substantially, our costs of operations could increase substantially and could impair our ability to make payments on the exchange notes. See the section entitled “Business – Government Regulation; Regulatory Matters—Merger Commitments.”

Increases in our leverage could lower our credit ratings thereby increasing the cost of obtaining financing in the capital markets and increasing our vulnerability to downturns in the economy and industry which reduce our sales, both of which would reduce cash flow from operations and decrease financial institutions’ willingness to provide capital. This reduced cash flow and reduced access to capital markets would result in a reduction in cash available for working capital, capital expenditures and for making payments on the exchange notes and other indebtedness.

Our business is capital intensive. In addition to operating cash flows, we rely on debt financings to fund our business. As of September 30, 2003, our total long term debt outstanding was approximately $424 million. The indenture governing the exchange notes does not prevent us from entering into a variety of acquisition, change of control, refinancing, recapitalization or other highly leveraged transactions. As a result, in the future, we could enter into any such transaction even though such transaction could increase the amount of our outstanding indebtedness. An increase in our leverage could adversely affect us by:

increasing the cash required for debt service. There may be a shortfall in free cash flow available for such debt service. Increased leverage could also lower our credit ratings thereby increasing

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increasing our vulnerability to general adverse economic and industry conditions. Such conditions can cause a reduction in sales thereby reducing free cash flow available for debt service. Additionally, such adverse conditions can cause in increase in interest rates and financing costs as well as reducing financial institutions willingness to provide credit and other financing, impacting our ability to make payments on the exchange notes and our other indebtedness;

limiting our ability to borrow additional funds or to obtain other financing for working capital, capital expenditures and other general corporate requirements;

requiring us to dedicate a substantial portion of our cash flow from operations to payments on our indebtedness, thereby reducing the availability of our cash flow to fund common dividends, working capital, capital expenditures and other general corporate purposes;

limiting our flexibility in planning for, or reacting to, changes in our business and the industry in which we operate; and

requiring us to manage a company subject to financial and other restrictive covenants. Failure to comply with those covenants could result in defaults, which if not cured or waived, could result in an acceleration of our outstanding debt.

Recent events in the energy markets that are beyond our control have increased the level of public and regulatory scrutiny in our industry and in the capital markets and have resulted in increased regulation and new accounting standards. Increased standards of compliance, monitoring and reporting, modifications in how we operate our business, or required changes in our financial reporting and accounting practices resulting from new accounting standards, laws or regulations could increase our costs and diminish our financial results. These events could reduce cash flow from operations and decrease our ability to make payments on the exchange notes and our access to capital.

As a result of the energy crisis in California during the summer of 2001, the volatility of natural gas prices in North America during the past year, the bankruptcy filing by Enron Corporation and other energy companies, accounting irregularities of public companies, and investigations by governmental authorities into energy trading activities, companies in the regulated and non-regulated utility businesses have been under an increased amount of public and regulatory scrutiny. Accounting irregularities at certain companies in the industry have caused regulators and legislators to review current accounting practices and financial disclosures. The capital markets and ratings agencies also have increased their level of scrutiny. It is difficult or impossible to predict or control what effect these events may have on our business, financial condition or access to the capital markets. Additionally, it is unclear what laws and regulations may develop, and we cannot predict the ultimate impact of any future changes in accounting regulations or practices in general with respect to public companies, the energy industry or its operations specifically. Any such new accounting standards, laws or regulations could increase standards of compliance, monitoring and reporting; require modifications in how we operate our business (such as been done in recent years in the environmental area); or require a change in our financial reporting and accounting practices in order to comply with Generally Accepted Accounting Principles. Such changes could increase our costs and diminish our financial results thereby reducing cash flow from operations and decreasing our ability to make payments on the exchange notes.

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We are subject to substantial governmental regulation. Compliance with regulatory requirements and procurement of necessary approvals, permits and certificates may result in substantial costs to us.

We are subject to substantial regulation from federal, state and local regulatory agencies. We are required to comply with numerous laws and regulations and to obtain permits, approvals and certificates from the governmental agencies that regulate various aspects of our business, including operation and construction of transmission facilities, customer rates, service regulations, retail service territories, sales of securities, asset acquisitions and sales, transactions between us and our affiliates, and accounting policies and practices. Additionally, the PUCT and the NMPRC have broad powers of supervision and regulation over us and the PUCT must approve the rates that we charge to REPs in Texas. We cannot predict the impact on our operating results from future regulatory activities of these agencies.

Given the newness of the competitive electricity market in Texas, existing laws and regulations governing the market structure could be reconsidered, revised or reinterpreted or new laws or regulations could be adopted. Any changes to such laws or regulations that impose new regulatory requirements on us or increase our costs could have a detrimental effect on our business. In recent years there has been significant legislative and regulatory activity throughout the United States, including Texas, to change the nature of regulation of our industry. Further alteration of the regulatory landscape in which we operate will impact the effectiveness of our business plan and may, because of the continued uncertainty, harm our financial condition and results of operations.

We have recorded a significant recoverable stranded cost, but recovery of such stranded cost is subject to review and approval by the PUCT. We may not ultimately recover the full amount of such stranded cost, thereby decreasing our results of operations and cash flows, and reducing the amount of funds available to consummate the mandatory securitization redemption of exchange notes to a level that would prevent the full redemption of outstanding exchange notes.

We are providing transmission and distribution services at regulated rates to customers within our service area. The 1999 Restructuring Legislation provides for recovery of “stranded costs”, the positive excess of the net book value of generation assets over the market value of the assets. Any such stranded costs would be recoverable from our Texas transmission and distribution customers.

We sold TNP One, our sole generation facility and only generation asset, in October 2002. Based on the sale, the fair value of TNP One, less cost to sell, was $117.5 million. The book value of TNP One at December 31, 2001, was approximately $418.5 million. We believe that the difference between the fair value of TNP One, net of selling costs, and its book value at December 31, 2001, is recoverable from our Texas transmission and distribution customers under the provisions of the 1999 Restructuring Legislation. Accordingly, we have recorded a regulatory asset for recoverable stranded cost of approximately $301.0 million.

Under the provisions of the 1999 Restructuring Legislation, the amount and manner of stranded cost recovery is subject to review and approval by the PUCT as part of the stranded cost true-up proceeding that will occur in 2004. Accordingly, action taken by the PUCT in the true-up proceeding could affect the ultimate recovery of the amounts recorded as recoverable stranded costs. Recovery of significantly less than the $301.0 million of estimated stranded costs currently recorded could have a material impact on our financial position and cash flows. Recovery of less than $250.0 million of stranded costs would prevent the full redemption of outstanding exchange notes in the mandatory redemption of such notes with the proceeds of the securitization of stranded costs. (See “Description of the Senior Notes—Redemption of the Senior Notes On or After May 1, 2005”).

There is uncertainty as to our recovery of deferred fuel balances and we may be denied full recovery of these fuel and energy-related purchased power costs, thereby decreasing our results of operations and cash flows.

Prior to the beginning of retail competition in Texas on January 1, 2002, we recovered fuel and the energy-related portion of purchased power costs from our customers in Texas through the fuel adjustment clause authorized by the PUCT. These costs are subject to adjustment or future reconciliation. As of September 30, 2003, we had an over-

~~Index to Financial Statements~~

recovered balance of fuel and energy-related purchased power costs of $24.3 million and currently show that amount as a liability to our customers. On April 1, 2003, we filed an application with the PUCT for the final reconciliation of our fuel and energy-related purchased power costs. This proceeding will reconcile fuel and energy-related purchased power costs incurred between January 1, 2000, and December 31, 2001, in accordance with the provisions of the 1999 Restructuring Legislation. On November 19, 2003, the administrative law judge assigned to this proceeding by the State Office of Administrative Hearings issued a proposed decision that recommends that the PUCT disallow $16.4 million of our fuel and energy-related purchased power costs during this period. The balance of fuel and energy-related purchased power costs ultimately resulting from the final fuel reconciliation will be included in the true-up proceeding for stranded costs that will occur in 2004. Subject to the results of the final fuel reconciliation, any over-recovered balance may reduce the amount of stranded costs we would be entitled to recover from our transmission and distribution customers. If the PUCT upholds the administrative law judge’s proposed decision and denies full recovery of these fuel and energy-related purchased power costs, then the amount shown as a liability to our customers would increase and our results of operations and cash flows would be diminished.

Rate regulation of our business may delay or deny us full recovery of our costs, thereby decreasing our results of operations and cash flows.

Our rates are regulated by the PUCT and the NMPRC through a rate proceeding and based on an analysis of our expenses incurred in a test year. Thus, the rates we are allowed to charge may or may not match our expenses at any given time. The PUCT or the NMPRC might judge some or all of our costs not to have been prudently incurred and therefore disallow full recovery of such costs. If costs were disallowed, it would cause our results of operations and cash flows to be diminished.

We are subject to the risk that our regulators will not permit recovery of material amounts of our purchased power costs or under-collections in New Mexico.

In New Mexico, we recover all purchased power costs through the fuel and purchased power adjustment clause authorized by the NMPRC, which is different than a rate proceeding. The purchased power recovery factor changes monthly to reflect over-collections or under-collections of the respective issues. If under-collections were disallowed, it would cause our results of operations and cash flows to be diminished.

We are subject to extensive environmental regulations that may increase the cost of our transmission and distribution of electricity.

Our business is subject to extensive environmental regulation by federal, state and local authorities. These laws and regulations affect the manner in which we conduct our operations and make capital expenditures. There are capital, operating and other costs associated with compliance with these environmental statutes, rules and regulations, and those costs could increase in the future. Moreover, environmental laws and the relevant standards and interpretations for compliance with such laws are subject to change, which may materially increase our costs of compliance or accelerate the timing of these capital expenditures, and which may not be fully recoverable from our customers.

We are subject to risks associated with a changing economic environment, including our ability to obtain insurance, the financial stability of our customers and our ability to raise capital. The presence of such risks could increase our interest costs and results of operations and adversely affect our ability to access the credit and capital markets and impair our results of operations and earnings.

Following the bankruptcy of Enron Corporation, the credit rating agencies initiated a thorough review of the capital structure and earnings power of energy companies, including us. These events could constrain the capital available to our industry and could limit our access to funding for our operations. Our business is capital intensive. If our ability to access capital becomes significantly constrained, our interest costs will likely increase and our financial condition and future results of operations could be significantly impaired.

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The continuation of the current economic downturn could also constrain the capital available to our industry and could reduce our access to funding for our operations, as well as the financial stability of our customers and counterparties. These factors could adversely affect our future earnings.

In addition, the availability of insurance covering risks that our competitors and we typically insure against has decreased. The insurance we are able to obtain has higher deductibles and higher premiums.

We are subject to insurance-related risks in a changing economic environment. Such risks could result in a reduction in the availability of insurance, a decrease in coverage, an increase in deductibles, an increase in premium expenses, and increased exposure to losses that exceed our insurance coverage or are subject to higher deductibles.

We carry property damage and liability insurance for our properties and operations. As a result of significant changes in the insurance marketplace, due in part to the September 11, 2001 terrorist acts, the availability of insurance covering risks our competitors and we typically insure against has decreased. In addition, the insurance we are able to obtain has higher deductibles and higher premiums. Insurance may not cover any or all of the lost revenues or increased expenses related to an insurance claim, which could erode our financial condition, results of operations, our cash reserves, and our ability to meet our cash obligations, including payments on the exchange notes and could increased exposure to losses that exceed our insurance coverage or are subject to higher deductibles.

Future terrorist attacks or acts of war could adversely affect our results of operations, future growth and ability to raise capital.

Future terrorist attacks or acts of war could affect our operations in unpredictable ways, such as increased security measures. Just the possibility that infrastructure facilities, such as electric transmission and distribution facilities, would be direct targets of, or indirect casualties of, an act of terror or war may affect our operations. War and the possibility of war may have an adverse effect on the economy in general. A lower level of economic activity might result in a decline in energy consumption, which may adversely affect our revenues or restrict our future growth. Instability in the financial markets as a result of war may affect our ability to raise capital.

Our business is dependent on our ability to successfully access capital markets. Our inability to access capital may limit our ability to execute our business plan.

Our business requires considerable capital resources. When necessary, we secure funds from external sources by borrowing from banks and, as required, issuing long-term debt securities. We actively manage our exposure to changes in interest rates through interest-rate swap transactions and our balance of fixed- and floating-rate instruments. We currently anticipate primarily using internally generated cash flows and short-term financing through bank borrowings to fund our operations as well as long-term external financing sources to fund capital requirements as the need arises. The ability to arrange debt financing, to refinance current maturities and early retirements of debt (with respect to which our liquidity needs could exceed our available resources), and the costs of issuing new debt are dependent on:

credit availability from banks and other financial institutions;

maintenance of acceptable credit ratings;

investor confidence in us and TNP Enterprises;

general economic and capital market conditions; and

the overall health of the utility industry.

If we are unable to secure funds to finance capital expenditures or working capital as needed due to factors such as those mentioned above, we may be unable to undertake maintenance or expansion projects of our energy delivery system, which could adversely affect the reliability of our transmission and distribution system and our ability to serve customers as well as achieve growth objectives; our liquidity and ability to pay operating costs of our

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business and make payments on the exchange notes may be harmed; and we may be unable to repay or refinance maturing securities.

A downgrade in our credit rating or a downgrade in the credit ratings of TNP Enterprises or First Choice could increase our cost of borrowing, which would diminish our financial results with the resulting decrease in free cash flow ~~and reduce~~reducing our ability to make payments on the exchange notes.

Our credit ratings are affected in part by the credit profile and credit ratings of the consolidated TNP Enterprises. To the extent that the credit ratings of TNP Enterprises or First Choice are downgraded, then our credit ratings could be downgraded.

Moody’s Investors Service (“Moody’s”), Standard & Poor’s Ratings Services (“S&P”), and Fitch Ratings (“Fitch”) rate our senior, unsecured debt at Baa3 (Outlook: Negative), BBB- (CreditWatch-Negative), and BB+ (Outlook: Stable), respectively. If Moody’s, S&P or Fitch were to downgrade our long-term rating, we would likely be required to pay a higher interest rate in future financings, our borrowing costs would ~~increase, which~~increase. Our financial results would ~~diminish~~be diminished and the resulting decrease in free cash flow would reduce our ~~financial results.~~ability to make payments on the exchange notes. In addition, our potential pool of investors and funding sources could decrease.

We are subject to control by our parent company, TNP Enterprises, which could act in a manner that would benefit TNP Enterprises to the detriment of our creditors, including the holders of the exchange notes.

We are a wholly-owned subsidiary of TNP Enterprises, and, therefore, TNP Enterprises controls decisions regarding our business and has control over our management and affairs. In circumstances involving a conflict of interest between TNP Enterprises, on the one hand, and our creditors, on the other, TNP Enterprises could exercise its power to control us in a manner that would benefit TNP Enterprises to the detriment of our creditors, including the holders of the exchange notes. For example, in the event of the financial distress or bankruptcy of TNP Enterprises, TNP Enterprises could cause us to pay the maximum amount of dividends allowable under regulatory, credit facility and indenture constraints, thereby causing a deficiency in free cash flow, which could adversely affect our ability to make payments on the exchange notes.

TNP Enterprises is not obligated to help maintain our capital or liquidity, which could adversely affect our ability to make payments on the exchange notes, our growth plans, our ability to raise additional debt and the evaluation of our credit by credit rating agencies.

TNP Enterprises is not obligated to provide any loans, further equity contributions or other funding to us or any of our subsidiaries, whether for the purpose of making payments due on the exchange notes, or for other purposes. We must compete with First Choice, the other subsidiary of TNP Enterprises, for capital and other resources. As a member of the TNP Enterprises corporate group, we operate within strategies and policies, including dividend strategies, established by TNP Enterprises that could affect our liquidity by reducing capital and cash reserves. See “Business.” The lack of necessary capital and cash reserves may diminish our ability to make payments on the exchange notes, our growth plans, our ability to raise additional debt and the evaluation of our creditworthiness by rating agencies.

TNP Enterprises and certain of its owners may have interests that conflict with your interests as holders of exchange notes; affiliates of CIBC World Markets Corp., which is an initial purchaser and lender to us, indirectly own interests in TNP Enterprises that may create conflicting interests. These conflicts could cause these persons to act in a manner that is to the detriment of the holders of the exchange notes.

SW Acquisition, L.P. (“SW Acquisition”), a Texas limited partnership, owns 100% of TNP Enterprises’ outstanding common stock. SW Acquisition’s owners include affiliates of CIBC World Markets Corp.(“CIBC World Markets”), which is an initial purchaser of the exchange notes. SW Acquisition controls TNP Enterprises, which in turn controls us. The interests of SW Acquisition and TNP Enterprises could conflict with your interests as a holder of exchange notes. Under certain circumstances, the interests of CIBC World Markets’ affiliates, as holders of limited partnership interests in SW Acquisition, and CIBC World Markets’ affiliate’s interest as a lender under our credit facility, may conflict with CIBC World Markets’ interests as an initial purchaser of the exchange notes. In the event of the financial distress or bankruptcy scenario of TNP Enterprises, SW Acquisition, TNP Enterprises and CIBC World Markets, as our direct and indirect owners, could cause us to pay the maximum amount of dividends allowable under regulatory, credit facility and indenture constraints, thereby causing a deficiency in free cash flow, which could adversely affect our ability to make payments on the exchange notes.

~~Index to Financial Statements~~

A trading market for the exchange notes may not develop, which could result in a loss or a decrease in the value of your investment or an inability to sell your exchange notes.

The existing notes constituted a new issue of securities with no established trading market. Although we are required under the registration rights agreement to commence an exchange offer to exchange the existing notes for exchange notes, which will be registered securities with substantially the same terms, or to register resales of the exchange notes under the Securities Act, we cannot assure you that such exchange or registration will occur or that an active trading market for the exchange notes or any securities exchanged for the exchange notes will develop. If a large number of holders of existing notes do not tender existing notes or tender existing notes improperly, the limited amount of exchange notes that would be issued and outstanding after we consummate the exchange offer could adversely affect the development of a market for the exchange notes. A small, illiquid trading market for the exchange notes with a limited number of participating investors could result in a loss or a decrease in the value of your investment or an inability to sell your exchange notes.

Existing notes that are not tendered for exchange in the exchange offer, or are not properly tendered for exchange, will continue to be subject to transfer restrictions.

We will only issue exchange notes in exchange for existing notes that you timely and properly tender. Therefore, you should allow sufficient time to ensure timely delivery of the existing notes and carefully follow the instructions on how to tender your existing notes. Neither the exchange agent nor we is required to tell you of any defects or irregularities with respect to your tender of existing notes.

If you do not exchange your existing notes for exchange notes pursuant to the exchange offer, the existing notes you hold will continue to be subject to transfer restrictions. In general, you may not offer or sell the existing notes except under and exemption from, or in a transaction not subject to, the Securities Act and applicable state securities laws. We do not plan to register existing notes under the Securities Act unless the registration rights agreement with the initial purchasers of the existing notes requires us to do so. Further, if you continue to hold any existing notes after the exchange offer is consummated, you may have trouble selling them because there will be fewer such notes outstanding.

We may have insufficient liquidity or access to capital upon an event of default under the indenture governing the exchange notes preventing us from fulfilling our obligations under the exchange notes.

The indenture governing the exchange notes provides that if certain events of default occur with respect to our outstanding senior debt securities, either the trustee or the holders of not less than 25% in aggregate principal amount of the outstanding senior debt securities may, upon notice as provided in the Indenture, declare the aggregate principal amount of all senior debt securities to be due and payable. The existing notes, exchange notes and the 6.25% Senior Notes due January 2009 currently comprise the senior debt securities with an aggregate principal amount outstanding of $425 million. We have no other debt currently outstanding. If an event of default were to occur, which resulted in acceleration in the repayment of our senior debt, we likely would not have sufficient liquidity or access to capital to repay our outstanding senior debt securities, including those obligations relating to the exchange notes. See the section entitled “Description of the Senior Notes—Events of Default” for more information.

~~Index to Financial Statements~~

The following table sets forth our ratio of earnings to fixed charges for the periods indicated.

The exchange offer is intended to satisfy our obligations under the registration rights agreement. We will not receive any cash proceeds from the issuance of the exchange notes in the exchange offer.

~~Index to Financial Statements~~

The following table sets forth the consolidated capitalization of us and our subsidiaries on an actual basis as of September 30, 2003 and as adjusted to give effect to the issuance of the exchange notes and their exchange in the exchange offer for the existing notes, which are substantially identical to the exchange notes.

You should read the information contained in the following table in conjunction with the “Use of Proceeds,” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” sections of this prospectus and our consolidated financial statements and related notes included elsewhere in this prospectus.

The exchange notes that are the subject of this exchange offer are substantially identical to the existing notes, and will be exchanged for the existing notes upon completion of the exchange offer.

~~Index to Financial Statements~~

The following tables set forth our selected historical financial and operating data for the nine months ended September 30, 2003 and 2002, and for the years ended December 31, 2002, 2001, 2000, 1999 and 1998. Income statement and balance sheet amounts have been derived from our audited financial statements. As the information below is only a summary and does not provide all of the information contained in our financial statements, you should read “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our consolidated financial statements dated December 31, 2002, consolidated interim financial statements and notes thereto included elsewhere in this prospectus.

We have derived the selected consolidated financial data as of and for the nine months ended September 30, 2002 and September 30, 2003 from our unaudited financial statements, which include all adjustments, consisting only of normal recurring adjustments, that in our opinion are necessary for a fair statement of financial position, results of operations and cash flows as of those dates and for those periods. The results of operations for the interim periods are not necessarily indicative of the results for the full years, due to the seasonality inherent in some of our operations and the possibility of general economic changes.

When retail competition began in Texas on January 1, 2002, we separated our previously integrated Texas utility operations into three components. First Choice assumed the activities related to the sale of electricity to retail customers in Texas and the results of those activities are no longer reflected in our consolidated financial statements. As a result, the amounts shown in our financial statements for 2002 are not comparable to prior years.

The historical information with respect to us as of December 31, 2002 and 2001, and for each of the three years in the period ended December 31, 2002 has been derived from our audited financial statements, which have been audited by Deloitte & Touche LLP, independent auditors. These financial statements appear elsewhere in this prospectus.

~~Index to Financial Statements~~

Retail competition began in Texas under the provisions of the 1999 Restructuring Legislation on January 1, 2002. In accordance with the 1999 Restructuring Legislation, we separated our Texas utility operations into three components. First Choice, our affiliated retail electric provider, assumed the activities related to the sale of electricity to retail customers in Texas, Texas Generating Company, L.P., a wholly owned subsidiary of ours, (“TGC”) became the unregulated entity performing the generation activities, and we continue to operate our regulated transmission and distribution business in Texas. The beginning of competition has resulted in a number of issues that affect our operations. As a company regulated by the PUCT in Texas and the NMPRC in New Mexico, we are not subject to competition.

Nonetheless, the beginning of competition has resulted in a number of issues that affected our operations. In particular, the Texas electric market opened to competition with a series of market-wide system and technical problems. These problems limited the ability of retail electric providers to switch customers from one retailer to another. In addition, the technical problems resulted in impaired data flows between the market participants. As a result, some of the bills we issued to customers were not accurate, and either overstated or understated the amount owed. We are required to cancel inaccurate bills and replace them with corrected bills. The overall effect was not significant to our financial condition, results of operations or cash flows. Other market participants were similarly affected. We have participated in efforts to improve the infrastructure and processes that support the competitive market. Those efforts have resulted in improvements in the switching process compared with its condition at the beginning of competition and the billing inaccuracies we experienced at the beginning of competition have decreased.

We provide transmission and distribution services at regulated rates to customers within our Texas service area. The 1999 Restructuring Legislation provides for recovery of “stranded” costs, the difference between the regulatory value of our investment in generation assets and the market price for energy in a competitive market. Any such stranded costs approved by the PUCT would be recoverable from our Texas transmission and distribution customers. The PUCT will conduct a proceeding in 2004 that will quantify and reconcile the amount of our recoverable stranded costs, if any. The proceeding will consider a number of issues, including the sale of TNP One that occurred in October 2002, the final fuel reconciliation and the amount of the clawback. The “clawback” is a provision of the 1999 Restructuring Legislation defined more fully in the Critical Accounting Policies section below.

We provide transmission and distribution services to various retail electric providers that, in turn, provide retail electric service within our service area. As of September 30, 2003, 27 retail electric providers served customers that receive transmission and distribution services from us, and First Choice provided electric service to 91 percent of the customers for whom we provide transmission and distribution services. The non-affiliated retail electric provider that provided electric service to the next highest number of our transmission and distribution customers served approximately 4 percent of our transmission and distribution customers.

We discuss the accounting policies that we and our subsidiaries employed in the preparation of the consolidated financial statements in Note 1 to the consolidated financial statements dated December 31, 2002. We are required to use estimates in order to prepare the consolidated financial statements in accordance with generally accepted accounting principles. Those estimates include accruals for estimated revenues for electricity delivered from the latest billing date to the end of the accounting period and estimated purchased power expenses incurred but not billed at the end of the accounting period. The use of these estimates is customary in the electric utility industry. Estimated revenues and purchased power expenses are adjusted to the actual amounts billed or incurred in the following month. We also employ certain critical accounting policies that require use of judgments and assumptions that are subject to uncertainty. The amounts reported in the consolidated financial statements that are related to

~~Index to Financial Statements~~

those critical accounting policies could be different if either different judgments were made or different assumptions were used. Those critical accounting policies are discussed below.

Clawback. First Choice is subject to a provision of the 1999 Restructuring Legislation commonly known as the “clawback.” The clawback would require First Choice to credit us the difference between the price-to-beat and the market price of electricity during the years 2002 and 2003. First Choice must offer former TNMP customers whose loads are less than 1 megawatt a regulated price, commonly called the “price-to-beat.” The price-to-beat will be offered through December 31, 2006, and First Choice cannot offer former TNMP customers any other rate before the loss of 40 percent of the energy consumed by its price-to-beat customers or January 1, 2005, whichever occurs first. Additional details regarding the clawback are discussed in Note 2 to both the consolidated financial statements dated December 31, 2002, and consolidated interim financial statements. First Choice increased the pre-tax reserve related to its estimated clawback liability of $12.7 million recorded at December 31, 2002, by $4.0 million for nine months ended September 30, 2003, which includes a $3.6 million increase in the third quarter of 2003. First Choice’s estimated clawback liability is based upon its current estimates of the number of competitive customers it will acquire and the number of price-to-beat customers it will lose through January 1, 2004.

Accounting for Derivatives – Normal Purchases and Sales. In the normal course of business we enter into commodity contracts, which include “swing” components for additional purchases of electricity, in order to meet customer requirements. In most circumstances, such contracts would be defined as derivatives under SFAS 133, “Accounting for Derivative Instruments and Hedging Activities.” However, the Financial Accounting Standards Board (“FASB”) has defined criteria by which option-type and forward contracts for electricity could qualify for the normal purchase and sales exception provided by SFAS 133. Based on the FASB’s guidance, we have determined that our contracts for electricity qualify for the normal purchases and sales exception. Accordingly, we do not account for our electricity contracts as derivatives.

If we were required to account for our electricity contracts as derivatives, the fair values of the contracts would be recorded on the balance sheet as assets or liabilities. Changes in the fair values of the contracts would be recognized in earnings.

Recoverable Stranded Costs – Sale of TNP One. We sold TNP One in October 2002. Based on the sale, the fair value of TNP One, less cost to sell, was $117.5 million. The book value of TNP One at December 31, 2001, was approximately $418.5 million. We believe that the difference between the fair value of TNP One, net of selling costs, and its book value at December 31, 2001, is recoverable from our Texas transmission and distribution customers under the provisions of the 1999 Restructuring Legislation. Accordingly, we have recorded a regulatory asset for recoverable stranded cost of approximately $301.0 million.

~~Index to Financial Statements~~

Nine Months Ended September 30, 2003 Compared to Nine Months Ended September 30, 2002

You should read the following discussion in conjunction with the related consolidated interim financial statements and notes.

We had income applicable to common stock of $12.3 million for the quarter ended September 30, 2003, compared with income applicable to common stock of $13.1 million for the quarter ended September 30, 2002. For the nine months ended September 30, 2003, we had income applicable to common stock of $28.2 million compared with income applicable to common stock of $29.3 million for the nine months ended September 30, 2002. The changes in our earnings for the quarter and nine months ended September 30, 2003 are attributable to the factors listed below (in millions):

The following table summarizes the components of our gross profit (in thousands).

Transmission expense is included in the “Other operating and maintenance” line of our consolidated income statement.

~~Index to Financial Statements~~

The following table summarizes the components of the change in our gross profit for the three and nine months ended September 30, 2003, compared with the same periods in 2002 (in thousands).

Gross profit for the three months ended September 30, 2003, decreased $7.6 million compared with the corresponding 2002 period. The overall decrease is attributable to the loss of revenue from the sale of TNP One output during 2002. We sold TNP One in October 2002. Lower sales in residential and commercial classes due to milder than normal weather also contributed to the decrease.

Gross profit for the nine months ended September 30, 2003, decreased $10.0 million compared with the corresponding 2002 period. The decrease is attributable to the loss of revenue from the sale of TNP One output described above. In addition, 2002 gross profit included revenues from the billing of bundled rates in January 2002 that were not present in 2003. The decrease was partially offset by higher electric service revenues, growth in the number of residential and commercial customers, and higher weather related sales.

Although retail competition began on January 1, 2002, our former customers were transferred to First Choice following their January 2002 meter reading. As a result, our January 2002 revenues include charges for service rendered through January 2002 meter reading dates at prices that reflect our integrated operations prior to competition. Beginning in February 2002, our revenues reflected rates designed to recover our cost of providing transmission and distribution service under the provisions of Senate Bill 7. Those rates are lower than the rates we charged prior to the beginning of competition, and resulted in decreased gross profit in the nine months ended September 30, 2003. The table above quantifies the impact of changing our rates to recover our cost of providing only transmission and distribution service.

In the first quarter of 2002, we sold the output of TNP One to First Choice at cost, which was 2.5 cents per kilowatt-hour (KWH). First Choice used the power to serve the load of its customers. Beginning in April 2002, we sold the output of TNP One to third parties at prices that averaged 2.8 cents per KWH, until the sale of TNP One in October 2002. We realized pre-tax income of $5.3 million related to third party sales for the nine months ended September 30, 2002.

Electric service revenues increased because we provided a greater number of fee-based services to retail electric providers in the nine months ended September 30, 2003, compared with the same period in 2002. The fee-based services included account initiation charges, service call charges, disconnect/reconnect charges and various metering charges, among others. Some of the charges for fee-based services that we provided to retail electric providers were included in the bundled rates we charged our customers prior to competition.

The $3.1 million gross profit increase described as “price/sales mix and other” for the nine months ended September 30, 2003, compared to the corresponding 2002 period, is primarily attributable to increased revenues from commercial and industrial customers in Texas. A significant portion of those customers’ revenues are calculated based upon those customers’ highest peak demand for electricity in the twelve month period ending in the month that the customers are billed. Customers’ bills through the third quarter of 2003 were based upon a full twelve months of demand data, but customers’ bills through the third quarter of 2002 were based upon less than twelve months of demand data due to the beginning of retail competition in January 2002. As a result, the 2002 bills were lower than they normally would be, because the demand data for the summer months of 2001, during which these customers typically have their highest demand, could not be included in the calculation of the customers’ bills.

~~Index to Financial Statements~~

Purchased power and fuel expenses decreased $9.0 million for the three months ended September 30, 2003, compared with the amount incurred in the same period in 2002. Expenses in 2002 included $11.3 million of TNP One fuel costs, which was sold in October 2002.

Purchased power and fuel expenses decreased $32.3 million for the nine months ended September 30, 2003, compared with the amount incurred in the same period in 2002. Expenses in 2002 included $33.4 million of TNP One fuel costs, which was sold in October 2002.

We incurred operating expenses of $44.3 million for the quarter ended September 30, 2003, a decrease of $16.5 million from the amount incurred during the corresponding period of 2002. For the nine months ended September 30, 2003, we incurred operating expenses of $135.8 million, a decrease of $44.2 million from the amount incurred during the corresponding period of 2002. The primary reason for the decreases for both the three and nine months ended September 30, 2003, compared with the corresponding 2002 periods was the absence of the operating expenses related to TNP One in 2003 resulting from the sale of TNP One in October 2002. We do not expect similar decreases in operating expenses in the future.

Operating expenses include purchased power and fuel, and transmission expense. Those expenses decreased $8.8 million and $31.4 million for the three and nine months ended September 30, 2003, compared with the same periods in 2002.

The details in the changes of purchased power and fuel, and transmission expense, are discussed above in“TNMP Gross Profit.” The remaining components of the changes in operating expenses are discussed below.

Other operating and maintenance expenses decreased $7.1 million and $10.5 million for the quarter and nine months ended September 30, 2003, compared with the same periods in 2002 respectively. The decrease is related to operating expenses of TNP One, which was sold in October 2002 and to TNMP’s establishment of a regulatory asset related to unrecovered System Benefit Fund payments, as discussed in Note 2 to the consolidated interim financial statements.

Taxes other than income taxes decreased $1.0 million and $3.7 million for the three and nine months ended September 30, 2003, compared with the corresponding 2002 periods. The decrease is primarily related to ad valorem taxes at TNP One, which was sold in October 2002.

Interest expenses increased $1.3 million and $4.1 million for the three and nine months ended September 30, 2003, respectively, compared to the same periods in 2002. The increase for the quarter is attributable to interest on $250 million of existing notes that we issued in June 2003. For the nine months ended, the increase reflects interest on the existing notes and $3.1 million of charges associated with the termination of our interest rate swaps upon the issuance of the existing notes in June 2003.

TNMP/First Choice Credit Facility. Until its expiration in October 2003, First Choice and we could borrow up to $90 million, in the aggregate, under the TNMP/First Choice Credit Facility. We could borrow subject to a guarantee by First Choice. There were no limitations on First Choice’s ability to guarantee our borrowings under the TNMP/First Choice credit facility. First Choice could borrow funds, or have letters of credit issued, under the credit facility subject to a guarantee by us. Our guarantee was limited to $75 million due to an order issued by the NMPRC in December 2001. Accordingly, First Choice’s borrowings and issuances of letters of credit were

~~Index to Financial Statements~~

limited to $75 million. The following sections discuss our liquidity following the expiration of the TNMP/First Choice Credit Facility.

TNMP Liquidity. On June 10, 2003, TNMP completed the sale of the existing notes. The proceeds from this sale were used to repay all of our outstanding borrowings under the TNMP/First Choice Credit Facility, which were $207 million as of June 10, 2003. At the same time, we reduced the commitment available for borrowing under that facility from $291.9 million to $90 million. As a result of the sale, TNMP has adequate cash to meet its working capital needs without the need for additional bank financing.

Our cash flow from operations for the nine months ended September 30, 2003 was $50.8 million higher than in the nine months ended September 30, 2002. The increased cash flow was primarily due to First Choice assuming our energy supply activities in Texas at the beginning of retail competition, which resulted in our making lower payments for fuel and purchased power costs in the first nine months of 2003. In addition, the sale of TNP One resulted in lower ad valorem tax payments in the first nine months of 2003 compared with the corresponding period in 2002.

We have sufficient liquidity to satisfy the possibility of any known contingencies. We believe cash flow from operations and cash on hand as a result of the issuance of the existing notes should be sufficient to meet working capital requirements at least through the end of 2005.

Expiration of TNMP/First Choice Credit Facility and Other Developments. The TNMP/First Choice Credit Facility expired in October 2003. As discussed inTNMP Liquidity, the issuance of the existing notes has provided us with adequate working capital without the need for additional bank financing.

In October 2003, the NMPRC granted our request for the authority to extend a portion of the guarantees that we provide for certain power supply obligations of First Choice. The NMPRC originally granted us authority to guarantee up to $75 million of First Choice obligations in December 2001. That authority was set to expire at the end of October 2003. We agreed to a number of conditions in return for the authority to guarantee First Choice’s power supply obligations, including the following:

we withdrew the request we made in June 2003 for authority to place our New Mexico operations in a separate wholly owned subsidiary of TNMP.

our authority to guarantee First Choice’s obligations is limited to $50 million. That amount will consist of our $25 million guarantee of First Choice’s performance under the Constellation power supply agreement and no more than $25 million in guarantees of First Choice’s performance under additional power supply agreements.

our authority to guarantee First Choice’s obligations ends on December 31, 2004, or on the date that First Choice executes power supply agreements that no longer require our guarantee, whichever occurs first.

we will not seek to recover any liability for performance under the guarantees from our New Mexico customers.

During the term of the guarantee, we will not seek to recover a cost of capital from our New Mexico customers other than the cost of capital that would be available to us if we had an investment grade credit rating, regardless of our actual credit rating.

Under the authority granted by the NMPRC we continue to guarantee $25 million of First Choice’s performance under the power supply agreement with Constellation.

TNMP Guarantees. The guarantee made by us requires us to assume the obligations of First Choice in the event of default. As of October 27, 2003, we had a maximum potential liability under our guarantee of First Choice performance under the Constellation agreement of $25.0 million. The guarantee will be in force until the earlier of December 31, 2004 or the date upon which Constellation releases us from our obligation to guarantee First Choice’s performance under the Constellation agreement, as described in Note 5 to the consolidated interim financial statements.

~~Index to Financial Statements~~

Intercompany Loans. Both the TNMP/First Choice Credit Facility and the Senior Credit Facility allow intercompany loans to be made between us and First Choice. As of June 30, 2003, all intercompany loans were retired. Due to the sale of the existing notes discussed inTNMP Liquidity, we do not expect to utilize intercompany loans in the foreseeable future.

When full retail competition began in Texas on January 1, 2002, we separated our previously integrated Texas utility operations into three components. Since First Choice has assumed the activities related to the sale of electricity to retail customers in Texas, the amounts shown in our financial statements for 2002 and 2001 are not comparable.

We had consolidated income applicable to common stock of $36.1 million for the year ended December 31, 2002, compared with a consolidated income of $50.9 million for the year ended December 31, 2001, and consolidated income of $41.9 million for the year ended December 31, 2000.

The changes in our earnings for 2002 compared to 2001, and 2001 compared to 2000, are attributable to the factors listed below (in millions):

The following table summarizes the components of our gross profit (in thousands).

Because of the separation of our formerly integrated Texas utility operations discussed above, the following discussion will examine the changes in our gross profit for 2002 compared with 2001, and for 2001 compared with 2000 separately.

~~Index to Financial Statements~~

Gross profit for the year ended December 31, 2002, decreased $83.6 million, or 31.3 percent compared with the corresponding 2001 period. The decrease resulted from the change in our business resulting from the beginning of retail competition and the change in our transmission revenue and expenses resulting from the annual PUCT allocation of transmission costs. As discussed in the remainder of this section, the beginning of retail competition resulted in our charging lower prices for the transmission and distribution service we provided to REPs beginning in 2002, as opposed to the prices we charged for integrated electricity service prior to 2002. In addition, the annual allocation of transmission costs by the PUCT reduced the revenue we received, and increased the charges we paid, for transmission service in the area served by the Electric Reliability Council of Texas, or “ERCOT,” during 2002. Details of our transmission revenue and expenses are discussed later in this section.

Operating revenues, excluding transmission, decreased $343.0 million for the year ended December 31, 2002, compared with the same period in 2001. Retail competition began in Texas on January 1, 2002. On that date, First Choice, our affiliated electric retail provider, assumed the activities related to the sale of electricity to retail customers in Texas. We provide transmission and distribution services to customers within our service area and our regulated rates reflect the cost of providing those services. These rates are lower than the rates we charged prior to the beginning of competition, when we billed our customers at rates that reflected our integrated electric utility services, which included generation, energy supply and customer service activities in addition to transmission and distribution. The revenue decrease in 2002 compared with 2001 is a result of our charging the lower rates that reflect only transmission and distribution in 2002.

Purchased power and fuel expenses decreased $269.2 million for the year ended December 31, 2002, compared with the amount incurred in the same period in 2001. The decrease occurred due to the transfer at the beginning of retail competition to First Choice of responsibility for energy supply activities that we formerly performed. As a result, amounts incurred by TNMP for energy supply were incurred by First Choice in 2002.

During February 2002, the PUCT implemented an updated method of allocating transmission costs within ERCOT. Our share of transmission costs within ERCOT was smaller in 2002 than in 2001. Accordingly, the updated allocation reduced the revenue that we realized from providing transmission service during the year ended December 31, 2002, and increased the payments we made for using the transmission facilities of other ERCOT utilities. The updated allocation caused us to incur $3.4 million of net transmission expense for the year ended December 31, 2002 compared with net transmission revenue of $6.4 million for the year ended December 31, 2001.

The following table summarizes our sales for the years ended December 31, 2002 and 2001 (amounts in thousands of MWh).

Residential sales increased in 2002 compared with 2001. The increase in sales is primarily attributable to increases in the number of residential customers, which increased to approximately 211,000 in 2002 from approximately 206,000 in 2001. Average use per customer grew less than 1 percent in 2002 from 2001. Industrial sales decreased significantly, reflecting the end of economy sales agreements with two cogeneration customers. Under the agreements, we purchased the output from the cogeneration customers, and resold that output to the two customers at very low margins. The agreements expired when retail competition began in January 2002. The increase in sales for resale reflects the sale of the output from TNP One to First Choice during the first quarter of 2002, and to third parties from April 2002 until the sale of TNP One in October 2002.

~~Index to Financial Statements~~

The following table summarizes the components of the change in our gross profit for the year ended December 31, 2001, compared with the same period in 2000 (in thousands).

Gross profit in 2001 decreased $15.4 million, or 5.4 percent, compared with 2000. The decrease resulted from lower weather-related sales in the residential class, reduced sales to a significant industrial customer under an economy sales arrangement and the effects of renegotiated contracts with large industrial customers in New Mexico and Texas during 2000. Base rate reductions, discussed below, and increased non-pass-through purchased power costs in Texas also contributed to the decrease. These decreases were offset in part by growth in the number of residential and commercial customers.

Effective January 1, 2001 and 2000, we implemented base rate reductions of 3 percent and 1 percent for Texas residential and commercial customers, respectively, under the terms of a Declaratory Order issued by the PUCT on December 6, 1999. The effects of those reductions were partially offset by provisions for rate refunds in Texas and New Mexico of $1.9 million that were recorded during the twelve months ended December 31, 2000.

Purchased power and fuel expenses increased $21.4 million for the year ended December 31, 2001, compared with the amount incurred in the same period in 2000. Pass-through expenses increased $19.2 million, reflecting higher energy prices in Texas and New Mexico, partially offset by reduced purchases due to lower sales. During 2001, pass-through expenses included fuel and energy-related purchased power costs in Texas and all purchased power costs in New Mexico. The fuel adjustment clause under which we recovered our fuel and energy-related purchased power costs in Texas ended when retail competition began on January 1, 2002.

Non-pass-through expenses increased $2.2 million in 2001 compared with 2000. The increase is attributable to a $2.4 million credit to our purchased power costs in 2000, resulting from a PUCT order to defer and amortize previously incurred costs.

We had net transmission revenue of $6.4 million for the year ended December 31, 2001, compared with net transmission revenue of $6.7 million for the year ended December 31, 2000. Our transmission revenues and expenses in 2001 reflected an updated allocation of transmission costs within ERCOT under a formula originally adopted by the PUCT in 1999.

We incurred operating expenses of $227.3 million for the year ended December 31, 2002, a decrease of $319.5 million from the amount incurred during the corresponding period of 2001. The assumption of the energy supply and customer service activities by First Choice at the beginning of retail competition in January 2002 was a primary factor in the decrease in our operating expenses. We do not expect similar changes in our operating expenses in the future.

Operating expenses include purchased power, fuel and transmission. Those expenses decreased $259.4 million.

~~Index to Financial Statements~~

We incurred operating expenses of $546.7 million for the year ended December 31, 2001, an increase of $6.5 million over the amount incurred during the corresponding period of 2000. Purchased power, fuel and transmission expense increased $21.7 million.

The details of the changes in purchased power and fuel, and transmission expense are discussed above in “TNMP Gross Profit.”The remaining components of the changes in operating expenses are discussed below.

Other operating and maintenance expenses for the year ended December 31, 2002 decreased $28.4 million compared with 2001. The decrease is primarily attributable to First Choice assuming customer service activities at the beginning of retail competition that we performed in 2001. In addition, we made payments of $3.6 million to the System Benefit Fund in 2001. In 2002, the costs of the System Benefit Fund are passed through to customers, and are not recorded in operating and maintenance expense. The System Benefit Fund was mandated by the 1999 Restructuring Legislation and requires utilities within Texas to contribute annually to a PUCT administered fund at a rate not to exceed 50 cents per megawatt hour through December 31, 2002 and a rate not to exceed 65 cents per megawatt thereafter. The fund is used to provide assistance to low-income customers, fund customer education programs and to reimburse schools for reduced property tax collections due to decreases in the taxable value of generation plants. The termination of our factoring arrangement discussed in Note 8 to the consolidated financial statements dated December 31, 2002 contributed approximately $3.0 million to the decrease.

As discussed in Note 5 of the Notes to Consolidated Financial Statements, we stopped depreciating TNP One in accordance with SFAS 144. As a result, depreciation of utility plant decreased $14.8 million during the twelve months ended December 31, 2002, compared with the corresponding period of 2001.

Depreciation of utility plant in 2001 was comparable to the amount recorded in 2000.

Effective with the start of retail competition on January 1, 2002, the earnings cap under which we operated in 2001 was no longer in effect. Accordingly, we are no longer required to accrue for excess earnings. During the twelve months ended December 31, 2002, the charge for recovery of stranded plant decreased $2.1 million compared with the same period in 2001. The decrease resulted from our no longer accruing for excess earnings, and, as discussed in Note 2 to the consolidated financial statements dated December 31, 2002, from our recording an adjustment to our 2001 excess earnings accrual in the first quarter of 2002.

Charge for recovery of stranded plant decreased $16.9 million in 2001 compared with 2000. The decrease reflects reductions in our earnings before the charge for recovery of stranded plant during 2001 due primarily to reductions in base revenues, as shown in the “TNMP Gross Profit”section, above, as well as higher allowed earnings caused by decreased interest costs and reduced debt levels.

Taxes other than income taxes for the year ended December 31, 2002, decreased $10.2 million compared with the same period in 2001. At the beginning of retail competition, First Choice became responsible for paying certain revenue-related taxes that we had been responsible for paying in 2001.

~~Index to Financial Statements~~

Interest charges decreased by $5.4 million for the year ended December 31, 2002, compared with 2001. The decrease was due to lower interest rates on the TNMP/First Choice Credit Facility. The decrease was partially offset by increased borrowings under the TNMP/First Choice Credit Facility that resulted primarily from the termination of the factoring arrangement discussed in Note 8 to the consolidated financial statements dated December 31, 2002.

Interest charges decreased $13.3 million for the year ended December 31, 2001, compared to 2000. The decrease was due to lower interest rates and reduced debt levels on the TNMP/First Choice Credit Facility.

Cumulative effect of change in accounting decreased $1.2 million for the year ended December 31, 2002, compared with the corresponding period in 2001, and increased $1.2 million for the year ended December 31, 2001, compared with the corresponding period in 2000. The changes reflect the charge TNMP recorded in the first quarter of 2001 to write off the balance of previously deferred major maintenance costs. Effective January 1, 2001, we began charging the costs of major maintenance to expense as incurred.

Pension Plans. We maintain a qualified defined benefit pension plan, retiree medical plan, and retiree life insurance plan that cover our and our subsidiaries’ eligible employees. We also maintain a supplemental executive retirement plan (“SERP”), which provides pension benefits in excess of amounts permitted for qualified plans under U.S. tax law to affected participants of the qualified pension plan.

Our retirement plan expense for the qualified pension plan, retiree medical plan, retiree life insurance plan and SERP was approximately $1.0 million, $0.8 million and ($0.2) million for 2002, 2001 and 2000, respectively.

Retirement plan expense has been calculated based upon a number of actuarial assumptions, including an expected long-term rate of return on pension plan assets of 9.0 percent for 2002 and 9.5 percent for 2001. Reducing this assumption by 50 basis points increased the 2002 retirement plan expense by approximately $0.4 million.

In developing the expected long-term rate of return assumption, we evaluated input from our actuary, including a review of asset class return expectations as well as long-term inflation assumptions developed by independent consultants and economists. Projected investment returns are based on equity and fixed income indices, which represent broad market expectations. Based on this input, we believe it is reasonable to assume that its pension plan investment strategy will generate long-term returns of at least 9.0 percent.

The expected long-term rate of return on pension plan assets is based on an asset allocation of 60 percent to equity index funds (with an expected long-term rate of return of approximately 10.5 percent) and 40 percent to fixed income index funds (with an expected long-term rate of return of 6.5 percent). We regularly review our actual asset allocation and periodically rebalance the target allocation based on stated bands of the composite price-earnings ratios of the S&P 500 index. We also rebalance periodically based on movement in the Treasury Inflation Protected Securities (“TIPS”) yield rates. As of December 31, 2002, the plan’s target allocation was 10 percent equity index fund, 10 percent fixed income fund, and 80 percent money market fund. We continue to believe that 9.0 percent is a reasonable long-term rate of return for our pension plan assets, despite the recent market downturn and current conservative asset allocation. The plan’s return on average plan assets during 2002 was approximately 6.5 percent, in a year when the total return of the S&P 500 index was approximately a negative 22.1 percent. We will continue to evaluate its actuarial assumptions, including the expected rate of return, at least annually, and will make adjustments as necessary.

We base our determination of retirement plan expense on a market-related valuation of assets, which reduces year-to-year volatility. The market-related valuation recognizes realized and unrealized gains or losses over a five-year period. Therefore, future asset values will be impacted as previously deferred realized and unrealized

~~Index to Financial Statements~~

gains and losses are recognized. Recent investment losses will be recognized in the market-related value of assets over the next five years.

The discount rate that we utilize for determining our benefit obligations and retirement plan expense is based on a review of long-term corporate bonds. The Moody’s Aa index as of December 31st has been used to establish the discount rate. The discount rate determined on this basis decreased from 7.25 percent at December 31, 2001 to 6.5 percent at December 31, 2002. The retirement plan expense is expected to increase by approximately $0.1 million for each 25 basis point decline in the discount rate.

The value of qualified pension plan assets has decreased from $90.0 million at December 31, 2001 to $88.4 million at December 31, 2002, primarily due to payments to beneficiaries. The decline in value and declining discount rates have reduced the funded status (the difference between plan assets and projected benefit obligation) for the qualified pension plan and SERP from $7.2 million at December 31, 2001 to $2.0 million at December 31, 2002.

As of December 31, 2002, our common equity and long-term debt ratios were 42.1 percent and 57.9 percent, respectively, compared to common equity and long-term debt ratios of 49.6 percent and 50.4 percent as of December 31, 2001, respectively. The separation of our Texas utility operations in accordance with the 1999 Restructuring Legislation resulted in the capitalization of First Choice by us, which reduced our equity ratio. Long-term debt levels increased slightly in 2002 compared with 2001. During 2002, increased borrowings under the TNMP/First Choice Credit Facility due to the termination of the factoring arrangement were substantially offset by use of proceeds from the sale of TNP One to retire debt outstanding under the TNMP/First Choice Credit Facility.

Our capital requirements through 2007, adjusted for the issuance of the existing notes, are projected to be as follows (amounts in millions):

The table below presents our aggregate contractual obligations as of December 31, 2002, adjusted for the issuance of the existing notes (amounts in millions):

References above are to the consolidated financial statements dated December 31, 2002.

~~Index to Financial Statements~~

We guaranteed First Choice’s borrowings and issuances of letters of credit under the TNMP/First Choice Credit Facility until its expiration in October 2003. We also guarantee First Choice’s performance under the power supply contract with Constellation.

The issuance of the existing notes, along with cash flow from our operations, is expected to be sufficient to meet our liquidity requirements without the need for additional financing. Accordingly, neither the guarantee under the TNMP/First Choice Credit Facility nor our guarantee of the performance of First Choice under its power supply agreement with Constellation have a direct bearing on our liquidity, capital resources, or credit risk support. However, the ability of First Choice to grow its operations depends on the availability of adequate credit capacity to First Choice. Our guarantees support the credit capacity of First Choice and that support enhances the liquidity of First Choice. First Choice and we are related parties under the common control of TNP Enterprises. Our financial condition is evaluated, in part, as a function of the consolidated financial condition of TNP Enterprises. Our guarantees of First Choice borrowings and issuances of letters of credit enhance the consolidated financial condition of TNP Enterprises and, as a result, our guarantees of First Choice benefit us.

In the section of Note 8 of the consolidated financial statements dated December 31, 2002, entitled “TNMP/First Choice Credit Facility,” we discuss the conditions under which we may be required to perform under our guarantees. We also disclose the maximum potential liability to which we may be exposed if we are required to perform.

Upon issuance of the existing notes, we reduced the commitment under the TNMP/First Choice Credit Facility from $291.9 million to $90 million. As discussed above, we do not expect to require additional financing to meet our working capital requirements.

As previously discussed in the “Financial Condition” section of this prospectus, the TNMP/First Choice Credit Facility expired in October 2003. In addition, the NMPRC extended our authority to guarantee the obligations of First Choice under its power supply agreements. Accordingly, we continue to guarantee $25 million of the obligations of First Choice under its power supply agreement with Constellation.

Accounting for Asset Retirement Obligations. We adopted SFAS No. 143, “Accounting for Asset Retirement Obligations,” on January 1, 2003. The adoption had no impact on our financial position, results of operations, or cash flows. As a result of the adoption of SFAS 143, we identified costs recorded in accumulated depreciation related to inclusion of removal costs of utility plant in our rates by the PUCT and NMPRC. Such costs do not arise from legal obligations. Rather, they represent long-standing regulatory policy to include charges for removal costs of utility plant in accumulated depreciation. As of December 31, 2002 and 2001, $35.8 million and $33.8 million, respectively, of estimated utility plant removal costs were included in accumulated depreciation.

SFAS 143 requires entities to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred, and capitalize a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its fair value each period, and the capitalized cost is depreciated over the useful life of the related asset. As discussed in Note 5 to the consolidated financial statements dated December 31, 2002, TNMP sold TNP One, its sole generating facility. As a result of the sale, TNMP does not have significant asset retirement obligations that would be subject to the provisions of SFAS 143.

~~Index to Financial Statements~~

Accounting for the Impairment or Disposal of Long-Lived Assets. TNMP adopted SFAS No. 144, “Accounting for the Impairment of Long-Lived Assets,” during the fourth quarter of 2001. SFAS 144 establishes a single accounting model for long-lived assets to be disposed of by sale. SFAS 144 requires entities to measure long-lived assets held for sale at the lower of the asset’s carrying amount or fair value less cost to sell and to cease depreciation. The statement also resolved a number of implementation issues related to long-lived assets held for sale. Details regarding the adoption of SFAS 144 can be found in Note 5 to the consolidated financial statements dated December 31, 2002.

Accounting for Guarantees. In the fourth quarter of 2002, the FASB issued Interpretation No. 45, “Guarantors Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others” (“FIN 45”). FIN 45 elaborates on the disclosures to be made by a guarantor in its interim and annual financial statements about its obligations under certain guarantees that it has issued. It also clarifies that a guarantor is required to recognize, at the inception of a guarantee, a liability for the fair value of the obligation undertaken in issuing the guarantee.

We and First Choice guarantee each other’s borrowings and issuances of letters of credit under the TNMP/First Choice Credit Facility. We also guarantee First Choice’s performance under the power supply contract with Constellation. The provisions of FIN 45 related to recognizing a liability at inception for the fair value of the guarantor’s obligation do not apply to these guarantees. However, the disclosure requirements do apply, and those requirements became effective for us as of December 31, 2002. Disclosures regarding the guarantees of TNMP and First Choice are included in Note 8 to the consolidated financial statements dated December 31, 2002.

Consolidation of Variable Interest Entities. In January 2003, the FASB issued Interpretation No. 46, “Consolidation of Variable Interest Entities” (“FIN 46”). FIN 46 addresses the nature of variable interest entities, and specifies the conditions under which such variable interest entities shall be included in the consolidated statements of a business enterprise. FIN 46 becomes effective immediately for variable interest entities created after January 31, 2003. The effective date for variable interests acquired prior to February 1, 2003 is the first fiscal year or interim period beginning after June 15, 2003. As of December 31, 2002, we do not have variable interests that would be subject to the provisions of FIN 46.

Derivative Instruments and Hedging Activities.We adopted SFAS No. 149, “Amendments of Statement 133 on Derivative Instruments and Hedging Activities” (SFAS 149), on June 30, 2003. The adoption had no impact on our financial position, results of operations, or cash flows. SFAS 149 amends SFAS 133 for decisions made by the Derivatives Implementation Group that required amendments to SFAS 133, in connection with other Financial Accounting Standards Board projects regarding financial instruments, and for implementation issues regarding the application of the definition of a derivative.

The FASB issued SFAS No. 150, “Accounting for Certain Financial Instruments with Characteristics of both Liabilities and Equity (SFAS 150), in May 2003. SFAS 150 establishes standards for how an issuer classifies and measures certain financial instruments with characteristics of both liabilities and equity. SFAS 150 requires that an issuer classify a financial instrument that is within its scope as a liability or, in some circumstances, as an asset. SFAS 150 becomes effective for TNMP during the first quarter of 2004. TNMP does not expect the adoption of SFAS 150 to have any effect on its financial condition, results of operations, or cash flows.

~~Index to Financial Statements~~

Our involvement in the trading of market risk sensitive instruments is minimal and does not have a material impact to our financial condition or results of operations.

We manage our exposure to interest rate risk through the proportion of fixed rate debt to variable rate debt in our total debt portfolio. To manage this mix, we may enter into interest rate hedges that allow interest rates on variable rate debt to move only within specified floor and ceiling levels, or allow us to effectively convert variable rate debt to fixed rates.

Our ratio of fixed rate debt to total debt was 51 percent and 51 percent at December 31, 2002 and 2001, respectively. During 2002, we used proceeds from the sale of TNP One to reduce the debt outstanding under the TNMP/First Choice Credit Facility by $33.1 million. Increased borrowing under the TNMP/First Choice Credit Facility as a result of the termination of the factoring arrangement offset the debt reductions. As of December 31, 2002, we had two open swap transactions designed to manage interest rate risk associated with the TNMP/First Choice Credit Facility. The notional amount of the swaps was $75 million each. Under the terms of the swaps, TNMP paid fixed rates of approximately 2.4 percent and 2.5 percent and received variable rates that were approximately 1.3 percent as of June 10, 2003. The swaps were terminated on that date when we used the proceeds from the sale of $250 million of the existing notes to repay our outstanding borrowings under the TNMP/First Choice Credit Facility. The fair value of the swaps at December 31, 2002, was a liability of $1.9 million, which was recorded on the balance sheet within the caption “deferred credits and other liabilities.”

The TNMP/First Choice Credit Facility expired in October 2003. We repaid outstanding amounts under this facility with the proceeds from the issuance of the existing notes. As a result of this issuance, we do not anticipate an immediate need for new bank financing, but we will evaluate entering into a new facility for cash management purposes.

~~Index to Financial Statements~~

We are a regulated utility operating in Texas and New Mexico. In Texas, we are a regulated utility engaged solely in the transmission and distribution of electricity. In New Mexico, we provide integrated electricity services under traditional cost of service regulation. Those services include transmitting, distributing, purchasing and selling electricity to our New Mexico customers. Traditional cost-of-service regulation is a method of regulation that sets rates that we can charge to our electricity customers based upon our cost of providing that service. The cost of providing that service includes a return on the capital we have invested and dedicated to providing electric service.

We and First Choice are wholly owned subsidiaries of TNP Enterprises, a holding company that transacts business through its subsidiaries. We have two subsidiaries, Texas Generating Company, L.P. (“TGC”), a Texas limited partnership, and Texas Company II, LLC (“TGC II”), a Texas limited liability company. We formed TGC and TGCII as Texas corporations to finance construction of TNP One, our sole generation facility. Until May 2001, we owned TNP One together with TGC and TGC II. At that time, we converted TGC and TGCII to their present forms and consolidated the ownership of TNP One into TGC to comply with the 1999 Restructuring Legislation.

Effective January 1, 2002, the 1999 Restructuring Legislation established retail competition in the Texas electricity market. Prior to January 1, 2002, we operated as an integrated electric utility in Texas, generating, transmitting and distributing electricity to customers in our Texas service territory. As required by the 1999 Restructuring Legislation, and in accordance with a plan approved by the PUCT, we separated our Texas utility operations into three components:

Ÿ Retail Sales Activities. First Choice assumed the activities related to the sale of electricity to retail customers in Texas, and, on January 1, 2002, our customers became customers of First Choice, unless they chose a different retail electric provider. First Choice and other retail electric providers now perform all activities with Texas retail customers, including acquiring new retail customers, setting up retail accounts, billing retail customers, acquiring power for resale to retail customers, handling customer inquiries and complaints, and acting as a liaison between the transmission and distribution companies and the retail customers.

Ÿ Power Transmission and Distribution. We continue to operate our regulated transmission and distribution business in Texas.

Ÿ Power Generation.TCG became the unregulated entity performing our generation activities in Texas. However, in October 2002, we and TGC sold TNP One to Sempra Energy Resources. As a result of the sale, TGC and TGCII neither own property nor engage in any operating activities and neither we nor any of our affiliates is currently in the power generation business. See “Business – Sale of TNP One.”

No payments or other consideration were exchanged between us, First Choice or TGC in connection with the separation.

In June 2003, we asked the NMPRC for permission to form a new wholly-owned subsidiary in 2003 to acquire and hold our New Mexico properties and to conduct our New Mexico operations, which accounted for approximately 16% of our assets at September 30, 2003, and approximately 18% of our net income for the twelve months ended September 30, 2003. The purpose of the new subsidiary was to disengage our customers in each state from the risks associated with the other, and to provide us with the flexibility to respond to the competitive aspects of the deregulated retail electricity market in Texas while eliminating any unnecessary risks to our New Mexico customers. In October 2003, we withdrew the request in connection with the approval of our request to guarantee certain power supply obligations of First Choice. You may find more information about this request in Note 2 to the consolidated interim financial statements.

As a wholly-owned subsidiary of TNP Enterprises, we are subject to its control. TNP Enterprises controls decisions regarding our business and has control over our management and affairs. As a member of the TNP

~~Index to Financial Statements~~

Enterprises corporate group, we operate within strategies and policies, including dividend strategies, that TNP Enterprises may establish from time to time. There are currently no formal dividend strategies or mandatory dividend requirements. We have agreed with the NMPRC that we will not pay excessive dividends to TNP Enterprises, and are required to provide notice to the NMPRC at least 15 days prior to the payment of any dividends. The NMPRC could prevent the payment of dividends that it deems excessive.

Neither TNP Enterprises, First Choice nor any other TNP Enterprises or TNMP subsidiary or affiliate will guarantee or provide other credit or funding support for any of the exchange notes.

On April 7, 2000, pursuant to an Agreement and Plan of Merger among TNP Enterprises, ST Acquisition Corp (“ST Corp.”) and SW Acquisition, L.P. (“SW Acquisition”), the parent of ST Corp. ST Corp. merged with and into TNP Enterprises (“Merger”). TNP Enterprises is the surviving corporation in the Merger. Prior to the Merger, TNP Enterprises was publicly held, and its common stock was listed on the New York Stock Exchange.

In October 2002, we and TGC sold our sole generating facility, TNP One, a two-unit, lignite-fueled generating plant, located in Robertson County, Texas, to Sempra Energy Resources, the power generation subsidiary of Sempra Energy. The sale completed a process that we started in response to the 1999 Restructuring Legislation, which required electric utilities to separate their power generation business activities from the regulated transmission and distribution business. As a result of the sale, neither we nor any of our affiliates is in the power generation business. The 1999 Restructuring Legislation also established various methods for quantifying stranded costs, one of which was the sale of generation plants.

Sempra Energy Resources paid us $120 million for TNP One. Costs of the sale were $2.5 million, including a payment of $1.3 million to Laurel Hill Capital Partners, a related party, for financial advisory services. TNMP used the net proceeds to retire $33.1 million of debt outstanding under the TNMP/First Choice Credit Facility and to pay a dividend to TNP Enterprises of $84.3 million.

Based on the sale, the fair value of TNP One, less the cost to sell, was $117.5 million. We believe that the difference between the fair value of TNP One, net of selling costs, and its book value of approximately $418.5 million at December 31, 2001, is recoverable from our Texas transmission and distribution customers under the provisions of the 1999 Restructuring Legislation. Accordingly, we recorded a regulatory asset for recoverable stranded cost of approximately $301.0 million. Under the provisions of the 1999 Restructuring Legislation, the amount and manner of stranded cost recovery is subject to review and approval by the PUCT as part of the true-up proceeding, which commences in January 2004. The 1999 Restructuring Legislation allows the PUCT 150 days to render a decision in the true-up proceeding from the day that the proceeding is filed. Based on that time limit, we expect to receive an order in the true-up proceeding in late June 2004. Recovery of significantly less than the $301 million of estimated stranded costs could have a material impact on our financial position and cash flows.

During the process of obtaining findings from the PUCT necessary for obtaining status for TNP One as an Exempt Wholesale Generator, intervenors raised issues regarding the reasonableness of the sales price of TNP One and the effect of the sale on the rates paid by our Texas transmission and distribution customers. The PUCT did not consider those issues at the time of the sale. Instead, the PUCT deferred consideration of those issues to the stranded cost true-up proceeding. The results of the final fuel reconciliation and the amount of the clawback, both of which are discussed in Note 2 to the consolidated financial statements dated December 31, 2002, will also be considered in the stranded cost true-up proceeding that commences in January 2004.

~~Index to Financial Statements~~

We and TGC are responsible for certain environmental liabilities resulting from our operation of TNP One related to environmental conditions that were pre-existing to the sale of TNP One but may not be discovered until after the sale. We have indemnified the purchaser through October 31, 2007 for such liabilities, which are limited to $10 million individually or in the aggregate. The purchaser of TNP One has indemnified us for liabilities arising after the sale of TNP One, to the extent the purchaser caused those liabilities. The indemnification obligation for any party is not triggered unless and until the aggregate amount of an indemnifiable loss equals or exceeds $1 million. We have purchased an environmental liability insurance policy to cover such liabilities, subject to a self-insured retention of $50,000 for each incident. The policy period is through October 31, 2007. TGC and we are in the process of repairing, at our sole expense, minor tears that existed in the liners of the evaporation ponds at TNP One prior to the sale. We and TGC are solely responsible for any environmental liabilities that can be attributed to the existence of those tears, and neither the indemnification trigger of $1 million nor the limit of $10 million apply to those liabilities.

We serve a market niche of smaller- to medium-sized communities. We provide electric service to more than 250,000 customers in 85 Texas and New Mexico municipalities and adjacent rural areas. Only three of the 85 communities in our service territory have populations exceeding 50,000. Our service territory is organized into two operating areas: Texas and New Mexico. In most areas that we serve, we are the exclusive provider of transmission and distribution services.

Our Texas service territory consists of three non-contiguous areas. One portion of this territory extends from Lewisville, which is approximately 10 miles north of DFW International Airport, eastward to municipalities near the Red River and to communities south and west of Fort Worth. A second portion of our territory includes the area along the Texas Gulf Coast between Houston and Galveston, and a third includes areas of far west Texas between Midland and El Paso. In Texas, we provide transmission and distribution service, through retail electric providers, to a variety of entities, including customers engaged in the agricultural, food processing, oil and gas, petrochemical, and tourism industries.

Our Texas operations lie entirely within the ERCOT region. ERCOT is the independent system operator that is responsible for maintaining reliable operations of the bulk electric power supply system in the ERCOT region, which is located entirely within Texas and serves about 85% of the electrical load in Texas.

Our New Mexico service territory includes areas in southwest and south central New Mexico. We engage in the transmission, distribution, purchase and sale of electricity to residential customers and a variety of commercial and industrial entities, including customers engaged in mining and agriculture, with copper mines as the major industrial customer. We purchase all electricity for our New Mexico customers’ needs and energy scheduling services under a long-term wholesale power contract with Public Service Company of New Mexico. Our electricity purchases under this contract, which extends through December 2006, are at fixed rates to provide price stability to our New Mexico customers.

We are subject to various federal, state and local regulations. We possess all necessary franchises, licenses and certificates to enable us to conduct our business. Within Texas, we are a rate-regulated electric transmission and distribution utility and are subject to the jurisdiction of the PUCT and certain municipalities with respect to rates and service.

We are subject in some of our activities, including the issuance of securities and the acquisition or disposition of properties in New Mexico, to the jurisdiction of the FERC. Our transmission and distribution activities in Texas are not subject to FERC regulation, because those activities occur solely within Texas. We are also subject to various federal, state and local regulations dealing with environmental matters.

~~Index to Financial Statements~~

Franchises and Certificates of Public Convenience and Necessity.Texas and New Mexico laws do not require an electric utility to execute a franchise agreement with a municipality to be entitled to provide or continue to provide electrical service within the municipality. A franchise agreement does, however, document the mutually agreeable terms under which the service will be provided within a municipality. We hold 82 franchises with terms ranging from 15 to 50 years, one franchise with a five-year term, and two franchises with indefinite terms from the 85 municipalities to which we provide electric service. These franchises will expire on various dates from 2003 to 2039. One Texas franchise, comprising two percent of total company revenues, is scheduled to expire in 2003. We intend to negotiate and execute a new or amended franchise agreement with this municipality to be effective before the existing franchise expires at the end of 2003. The sales within the 85 franchises currently contribute approximately 64 percent of our total revenues.

We also hold PUCT certificates of public convenience and necessity covering all Texas areas that we serve. These certificates include terms that are customary in the public utility industry. We generally have not been required to have certificates of public convenience and necessity to provide electric service in New Mexico. In both Texas and New Mexico, we are the exclusive transmission and distribution provider in nearly all of the areas we serve.

Texas. The 1999 Restructuring Legislation implemented competition in Texas retail electric markets. Under that legislation, utilities will be able to recover 100% of their net verifiable stranded costs through accelerated depreciation and competitive transition charges, or “CTCs.” Stranded costs represent the excess of an asset’s book value over its market value. CTCs are charges that utilities have been permitted to assess since the beginning of 2002. The 1999 Restructuring Legislation also permits utilities to securitize regulatory assets and up to 75% of their stranded costs, enabling them to accelerate their recovery of stranded costs.

Unbundled Cost of Service. Our current transmission and distribution rates in Texas were established by an October 31, 2001 final order issued by the PUCT in a rate case proceeding called an “Unbundled Cost of Service” or “UCOS” proceeding. We filed our UCOS case in March 2000 as required by the 1999 Restructuring Legislation in order to set our transmission and distribution rates for the period after the January 2002 commencement of competition. The final order established our transmission and distribution cost of service, approved our plan separating utility operations in compliance with the 1999 Restructuring Legislation and included an initial estimate of stranded costs, also called Excess Cost Over Market, or “ECOM.”

The actual amount of stranded costs differs from the PUCT’s initial estimation. As discussed above under “Sale of TNP One”, we have recorded a regulatory asset for recoverable stranded cost of approximately $301.0 million. The amount and manner of stranded cost recovery is subject to review and approval by the PUCT as part of the 2004 true-up proceeding.

New Mexico.During 2003, the New Mexico legislature repealed the New Mexico Restructuring Act, the legislation under which the electric utility business was to be deregulated in that state. This Act, which was enacted in 1999 but never implemented, had no impact on us.

2001 Rate Case. Our rates in New Mexico were established in a rate case filed during 2001 and went into effect February 1, 2002. The stipulation among the parties setting out the terms of the settlement of that case allows us to defer costs related to the now cancelled transition to competition for consideration by the NMPRC in a future proceeding.

Merger Commitments. As conditions for approval of the Merger, we made a number of commitments to both the PUCT and the NMPRC. The commitments cover a wide range of financial, operational, electric reliability and other standards that we agreed to honor. We made 55 such commitments, of which 47 are currently in effect. We monitor compliance on a monthly basis and could be subject to financial penalties for noncompliance with certain commitments. During the years ended December 31, 2002 and 2001, we were not in compliance with one commitment regarding electric reliability standards in Texas, and, as a result, paid $0.2 million in penalties during the second quarter of 2003.

~~Index to Financial Statements~~

Several commitments and assurances were primarily designed to ensure that TNP Enterprises and TNMP would be operated as separate entities following the Merger, and that our assets would not be used, to the detriment of rate payers, to satisfy the obligations of TNP Enterprises.

commit to a guaranteed level of stranded cost mitigation equal to $59.0 million less base rate reductions in 2000 and 2001;

strive to maintain our investment grade rating while placing a high priority on maintaining the financial integrity of our utility operations;

with respect to our transmission and distribution businesses, strive to maintain a 70% maximum debt to total capitalization ratio through January 1, 2004; and

limit our payments of dividends to TNP Enterprises unless certain financial tests are satisfied, including limiting dividends to the cumulative amount of cash flow from operations less cash flow from investing before January 1, 2004.

Additionally, TNP Enterprises agreed that, in connection with any future borrowings, it would require acknowledgments from its lenders, as long as we have rated debt outstanding, that:

TNP Enterprises and TNMP will be operated as separate corporate and legal entities;

by agreeing to make new loans, those lenders are relying solely on the creditworthiness of TNP Enterprises and not us; and

TNP Enterprises will not be permitted to take any steps for the purposes of procuring the appointment of a receiver or institute a bankruptcy, reorganization, insolvency, wind-up or liquidation of TNMP.

Before the NMPRC, TNP Enterprises made similar and additional commitments with respect to us, including that we would:

not pay excessive dividends to TNP Enterprises;

furnish a notice of our declaration to pay a dividend to TNP Enterprises, specifying the amount of the dividends to be paid, the cumulative amount of the dividends for the calendar year, and the net income and the payout ratio for the two preceding calendar years;

not purchase debt instruments or any affiliated interests or guarantee or assume liabilities of affiliated interests without state regulatory approval;

not purchase power (not applicable to economy energy purchases) from an affiliate without receiving prior NMPRC approval;

not lend or transfer funds or securities or similar assets to affiliated interests without state regulatory approval;

not obstruct, hinder, diminish, impair or unduly complicate its supervision and regulation;

if required by the NMPRC, have a management audit performed by a consulting firm chosen by and under the direction of the NMPRC to determine whether there are any adverse effects of affiliate transactions upon us, and have an allocation study of transactions between us and our affiliates performed by a consulting firm chosen by and under the direction of the regulatory authorities;

hold our customers harmless from any and all negative impacts of the affiliate transactions involved in the acquisition of TNP Enterprises’ stock; and

keep our books and records separately from those of our non-regulated business and in accordance with the Uniform System of Accounts.

~~Index to Financial Statements~~

not take any action that would have a material adverse effect on our ability to provide reasonable and proper service at fair and just rates;

ensure that no TNP Enterprises debt would contain provisions that are inconsistent with TNP Enterprises and TNMP being operated as separate corporate and legal entities, and a recognition that TNP Enterprises’ creditors are relying solely on the creditworthiness of TNP Enterprises; and

ensure that no TNP Enterprises debt would contain provisions allowing TNP Enterprises’ creditors to 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 proceeding under applicable law in respect of us or any of our subsidiaries.

Additionally, we and TNP Enterprises committed that our assets will not be pledged to pay for or guarantee the debt of any of our affiliates without prior approval of the PUCT and the NMPRC.

Regulatory Approval of Certain Transactions. In addition to the agreements described above, we are also subject to additional regulation in New Mexico with respect to certain transactions, particularly those with affiliated companies. For example,

proceeds from our issuance of debt will generally be available only for the acquisition of utility property, the construction, completion, extension or improvement of our facilities, the improvement or maintenance of service, the discharge or lawful refunding of our obligations or the reimbursement of money actually expended for the foregoing;

prior approval is required for the transfer of utility assets or for the abandonment of any service;

cross-subsidization and improper cost allocation between us and our affiliates is prohibited;

prior notice of any sale, lease or provision of real property, water rights or other goods or services to an affiliate is required, and the NMPRC may issue orders on any such transactions to ensure reliable service at fair, just and reasonable rates; and

prior approval is required for any acquisition by TNP Enterprises of our stock or consolidation with us, or any transaction that results in control or exercise of control of us.

We experience increased sales and operating revenues during the summer months as a result of increased air conditioner usage in hot weather. In 2002, approximately 37 percent of our annual revenues were recorded in June, July, August and September.

At September 30, 2003, we had 569 employees. No employees are represented by a union or covered by a collective bargaining agreement. Management believes relations with its employees are good.

We are a Texas corporation. Our predecessor was organized in 1925. The mailing address for our principal executive offices is 4100 International Plaza, P.O. Box 2943, Fort Worth, Texas 76113. Our telephone number is (817) 731-0099.

Transmission and Distribution Facilities.Our facilities are located within our Texas and New Mexico service areas. Our Texas transmission and distribution facilities are located in three non-contiguous areas. One area extends from Lewisville, which is approximately 10 miles north of DFW International Airport, eastward to municipalities near the Red River and to communities south and west of Fort Worth. A second area includes portions of Galveston and Brazoria counties, located along the Texas Gulf Coast between Houston and Galveston,

~~Index to Financial Statements~~

and a third includes areas of far west Texas between Midland and El Paso, extending from the cities of Kermit and Pecos south to Fort Stockton and Sanderson. Our New Mexico transmission and distribution facilities are located in southwest and south central New Mexico, including the cities of Alamogordo, Ruidoso, Silver City, Lordsburg and surrounding communities.

Management believes that our transmission and distribution facilities have sufficient capacity to serve existing customers adequately and that those facilities can be extended and expanded to serve customer growth for the foreseeable future. These facilities primarily consist of overhead and underground lines, substations, transformers, and meters. We generally construct our transmission and distribution facilities on easements or public rights of way and not on real property held in fee simple.

Administrative and Service Facilities. Our corporate headquarters are located in an office building in Fort Worth, Texas. We have leased space in this building through October 2007.

We own or lease 26 construction centers or other office facilities in Texas and New Mexico. In addition to these facilities, we own or lease offices in 12 Texas communities that we share with First Choice. This sharing of facilities is allowed through a waiver granted by the PUCT.

Retail Competition.Retail competition began under the provisions of 1999 Restructuring Legislation on January 1, 2002. In accordance with the 1999 Restructuring Legislation, we separated our Texas utility operations into three components. First Choice, our affiliated retail electric provider, assumed the activities related to the sale of electricity to retail customers in Texas; TGC became the unregulated entity performing generation activities. We continue to operate our regulated transmission and distribution business in Texas. The operations of TGC are included in our consolidated financial statements. In October 2002, we and TGC sold TNP One, our sole generating unit, to Sempra Energy Resources. As a result of the sale, TGC no longer performs generation activities.

First Choice must offer former TNMP customers whose loads are less than 1 megawatt a regulated price, commonly called the “price-to-beat.” The price-to-beat will be offered through December 31, 2006, and First Choice cannot offer former TNMP customers any other rate before the loss of 40 percent of the energy consumed by its price-to-beat customers, or January 1, 2005, whichever occurs first.

Final Fuel Reconciliation. The beginning of retail competition affected the methods by which companies recover their purchased power and fuel costs. Prior to December 31, 2001, we recovered fuel and the energy-related portion of purchased power costs from customers through the fuel adjustment clause authorized by the PUCT. The demand-related portion of purchased power was recovered through base rates and, unlike the fuel and energy-related portion, was not subject to adjustment or future reconciliation. Effective January 1, 2002, First Choice assumed the energy supply activities related to the sale of electricity to retail customers in Texas.

As of September 30, 2003, we had an over-recovered balance of fuel and energy-related purchased power costs of $24.3 million. On April 1, 2003, we filed an application with the PUCT for the final reconciliation of its fuel and energy-related purchased power costs. This proceeding will reconcile fuel and energy-related purchased power costs incurred between January 1, 2000, and December 31, 2001, in accordance with the provisions of the 1999 Restructuring Legislation. On November 19, 2003, the administrative law judge assigned to this proceeding by the State Office of Administrative Hearings issued a proposed decision that recommends that the PUCT disallow $16.4 million of our fuel and energy related purchased power costs during this period. We expect the PUCT to render its final disposition in this proceeding in mid-December 2003, but cannot predict what its final decision will be. The balance of fuel and energy-related purchased power costs resulting from the final fuel reconciliation will be included in the true-up proceeding for stranded costs that will occur in 2004. Subject to the results of the final fuel reconciliation, any over-recovered balance may reduce the amount of stranded costs we would be entitled to recover from our transmission and distribution customers.

Clawback. The 1999 Restructuring Legislation includes a provision, commonly known as the “clawback,” that would require First Choice to credit us the difference between the price-to-beat and the market price of

~~Index to Financial Statements~~

electricity during the years 2002 and 2003. The PUCT will determine the amount of the clawback credit in the true-up proceeding that will occur in 2004. Our maximum credit is limited to $150 multiplied by the difference between the number of First Choice price-to-beat customers and the number of First Choice competitively acquired residential and small commercial customers as of January 1, 2004. Based on current projections, First Choice estimates that its clawback liability will be $16.7 million. Accordingly, First Choice increased its pre-tax reserve of $12.7 million recorded at December 31, 2002, by $4.0 million for the nine months ended September 30, 2003, which includes a $3.6 million increase in the third quarter of 2003.

2001 Excess Earnings. In March 2002, we filed our Annual Report with the PUCT. The Annual Report detailed our calculation of excess earnings under the provisions of 1999 Restructuring Legislation. The Annual Report showed that we had no excess earnings for the year ended December 31, 2001, and, in fact, reported a deficiency of $3.1 million. Accordingly, our financial results for the twelve months ended December 31, 2002, reflect the reversal of $0.7 million of excess earnings that had been estimated and accrued as of December 31, 2001.

The $3.1 million deficiency shown in our Annual Report is attributable to payments of $3.6 million that we made in 2001 to the System Benefit Fund mandated by the 1999 Restructuring Legislation. This Fund was established to assist school districts that are losing tax revenues as a result of deregulation and low-income customers who need assistance on energy efficiency projects and their energy bills. The PUCT has concluded that utilities that do not have sufficient earnings to cover their System Benefit Fund payments may petition the PUCT for relief. Accordingly, we filed a petition in November 2002 asking the PUCT to allow us to establish a regulatory asset of $3.1 million, the amount of our 2001 Annual Report earnings deficiency that is attributable to System Benefit Fund payments. The petition has been referred to the State Office of Administrative Hearings, and a hearing on the merits of the petition was held on April 25, 2003. In August 2003, the PUCT gave us authorization to record the $3.1 million regulatory asset and to accrue a return on that regulatory asset at 8.5 percent beginning on December 31, 2001.

In July 2002, FERC issued a Notice of Proposed Rulemaking regarding Standard Market Design. The goal of the proposed rulemaking is to create a standardized design for the wholesale transmission service market. The proposed rulemaking creates a schedule that would result in the provisions of the proposed rule becoming effective at various times in 2003 and 2004. We will monitor the development of the proposed rule to assess its effects on our cost of providing transmission service in New Mexico.

~~Index to Financial Statements~~

TNP Enterprises controls TNMP and elects our board of directors annually. Each member of the board of directors holds office until a successor is elected and qualified or until resignation or removal. Our board of directors elects our officers and each of our officers serves at the discretion of the board of directors.

William J. Catacosinos, 73, has been Chairman, President and Chief Executive Officer of TNP Enterprises since the closing of the Merger in April 2000. He also serves on our board of directors. Since November 1998, Dr. Catacosinos has also served as Managing Partner of Laurel Hill Capital Partners. Dr. Catacosinos served as Chairman and Chief Executive Officer of Long Island Lighting Company (“LILCO”) from January 1984 to July 1998.

Jack V. Chambers, 54, has served as our Chairman, President and Chief Executive Officer since April 2001. Mr. Chambers was our Senior Vice President and Chief Operations Officer from October 2000 to April 2001. He was our Senior Vice President and Chief Customer Officer from 1994 until October 2000, and was a Senior Vice President of TNP Enterprises from April 1996 until the closing of the Merger in April 2000.

James T. Flynn, 69, became a director of TNMP at the time of the Merger in April 2000 and of TNP Enterprises in November 2000. Mr. Flynn, prior to his retirement, was President and Chief Operating Officer of LILCO from December 1996 to January 1999.

Preston M. Geren III, 51, became a director of both TNP Enterprises and TNMP at the time of the Merger in April 2000. Mr. Geren has served as Special Assistant to the Secretary of Defense since August 2001. He was a management consultant for Public Strategies, Inc. from February 1997 until August 1998. He is also an attorney and managed personal business interests in real estate, oil and gas, and securities from August 1998 until August 2001. Mr. Geren currently has served on the board of directors of Cullen Frost Bankers (NYSE) since January 1999 and Anadarko Petroleum Corp. (NYSE) since January 1999. He was a member of the United States Congress representing the Twelfth Congressional District of Texas from September 1989 until January 1997.

Leeam Lowin, 57, became a director of both TNP Enterprises and TNMP at the time of the Merger in April 2000. For the past 36 years, Mr. Lowin has been an investment manager for private accounts. From 1984 to 1998, Mr. Lowin served as a consultant to LILCO. From July 1992 to March 1996, he was a member of the board of directors of AEL Industries and managed the sale of that company to Tracor.

Our Board of Directors maintains two standing committees, an Audit Committee and a Compensation Committee.

Audit Committee. This committee oversees the financial reporting process; reviews the annual and quarterly financial statements; approves the appointment and fees of, and performance of any nonaudit services by, the independent accountants; evaluates the performance of the independent accountants; reviews the internal audit function; meets with the independent accountants and with appropriate financial personnel and internal auditors regarding corporate financial reporting, accounting procedures and controls, and the scope of internal and independent audits; and evaluates officers’ compliance with ethics policies, national and state laws and regulations related to securities, criminal conduct and the environment. The members of the Audit Committees are Messrs. Flynn and Lowin. Mr. Flynn is the Chair of the committee.

Compensation Committee.This committee reviews the performance of our officers and establishes the appropriate level of base compensation ranges and specific base salaries within such ranges for the officers who report to the Chief Executive Officer; recommends actions with respect to adoption, amendment, administration or termination of compensation, welfare, benefit, pension and other plans related to compensation of employees; reviews the terms and conditions of all employee benefit plans; establishes performance goals for all incentive

~~Index to Financial Statements~~

compensation plans; oversees the management organization; and makes recommendations to the full board with respect to directors’ compensation. Messrs. Flynn and Lowin are members of our Compensation Committee. Mr. Lowin chairs the committee.

Meetings.During 2002, our board of directors held five meetings. The Audit Committee held four meetings and the Compensation Committee held five meetings. All directors attended at least 75 percent of the meetings of the Board of Directors and committees on which they served during 2002.

Each of our non-employee directors is also a director of TNP Enterprises. Each non-employee director receives an annual retainer of $20,000 from TNP Enterprises and $28,000 from us, and a fee of $1,250 for each meeting of the TNP Enterprises and TNMP boards and committees that he attends. Directors and committee members are also reimbursed for travel and other incidental expenses incurred in connection with their duties. Directors who are employees receive no additional compensation for serving as directors.

No Compensation Committee member is a director of or serves on the compensation committee of an entity that has an executive officer serving on TNP Enterprises’ Board of Directors or Compensation Committee.

Our executive officers, who are elected annually by the board of directors and serve at the discretion of the board, are as follows:

Scott Forbes became our Senior Vice President & Chief Financial Officer in July 2003. He served as our Senior Vice President & Chief Financial and Accounting Officer from August 2002 to July 2003. Previously, he had served as our Vice President – Chief Accounting & Information Officer since January 2001. Prior to that, he had served as our Chief Accounting & Information Officer since April 2000. He was elected our Chief Information Officer in June 1998. He was our Controller from February 1997 to June 1998 and was Controller of TNP Enterprises from May 1997 to June 1998.

W. Douglas Hobbs became Senior Vice President & Chief Operations Officer in August 2002. He had served as our Vice President – T&D Operations since June 2002. Prior to that, he had served as our Vice President – Texas Transmission and Distribution Operations since October 2000. He was our Vice President and Regional Customer Officer from March 1999 to October 2000. He served as Vice President – Business Development of TNP Enterprises from May 1997 until May 1999.

Melissa D. Davis was appointed our Vice President – Human Resources effective March 1999. She served as our Vice President and Regional Customer Officer from February 1997 until March 1999.

~~Index to Financial Statements~~

Michael D. Blanchard became our Vice President & General Counsel in February 1998. He also served as Vice President & General Counsel of TNP Enterprises from February 1998 until the closing of the Merger. He was Corporate Secretary and General Counsel of TNMP and TNP Enterprises from 1987 to February 1998.

Joseph B. Hegwood was elected Vice President & Controller in August 2003. He was also named Chief Accounting Officer at that time. He was our Assistant Controller from August 2002 to August 2003. From July 2002 to August 2002, he served as our Director of Accounting. He served as our Director of Finance from July 2000 to July 2002. He was our Manager of Budgets, Projects & Property Accounting from July 1998 to July 2000. From April 1998 to July 1998, he served as our Supervisor of Budgets, Projects & Property Accounting. From November 1997 until April 1998, he served as our Supervisor of Projects & Property Accounting.

Adam Cartebecame our Vice President & Treasurer in August 2003. Prior to joining us, Mr. Carte served in several treasury and finance positions with NRG Energy, Inc., of Minneapolis, Minnesota. He was NRG’s Vice President and Treasurer from 2002 until joining us, its Assistant Treasurer from 2000 to 2002, Director of Treasury Operations and Corporate Finance from 1999 to 2000, and Senior Treasury Analyst / Treasury Analyst / Treasury Assistant from 1995 to 1999.

Georgia (Cookie) Chambers has served as our Chief Information Officer since September 2002. From 1999 through 2001, she served as Vice President of Information Technology for Paging Network, Inc. and from 1997 through 1998, she served as Director of Application Development. Ms. Chambers is unrelated to Jack V. Chambers.

Paul W. Talbot was elected our Corporate Secretary in February 1998. He was elected Corporate Secretary of First Choice in August 2001. He served as Corporate Secretary of TNP Enterprises from February 1998 until the closing of the Merger. He has been Senior Counsel of TNMP since August 1996.

B. Jan Adkins became our Assistant Corporate Secretary in August 1987. She also served as Assistant Corporate Secretary of TNP Enterprises from August 1987 until the closing of the Merger.

TNP Enterprises owns all of our common stock. There is no public trading market for our common stock.

The following table lists the common stock of TNP Enterprises owned by our directors and executive officers of TNMP at September 30, 2003. SW Acquisition, L.P. owns 100 percent of the common equity interests of TNP Enterprises.

~~Index to Financial Statements~~

The following table summarizes the compensation paid to our Chief Executive Officer and our other most highly compensated executive officers (the “Named Executive Officers”) for services rendered in all capacities to us and to our affiliated companies during 2000, 2001 and 2002.

~~Index to Financial Statements~~

The pension plan is a noncontributory defined benefit plan. Effective October 1, 1997, we amended our pension plan to change it to a cash balance retirement plan. As amended, the pension plan provides benefits based on an account balance rather than a formula-based benefit. Employees who, as of October 1, 1997, were at least 55 years of age, or were at least 50 years of age and had at least 10 years of service, can be “grandfathered” in the prior pension plan, and will receive benefits under the plan that provides the greater retirement payments.

The amended pension plan bases its benefits on an employee’s account balance when he or she retires or leaves the company. An employee’s initial account balance was based on his or her accrued pension benefits under the pre-amendment plan or at the time of his or her employment. The account balance grows as we add benefit credits consisting of a percentage of compensation and interest credits based on one-year Treasury constant maturities rates. All employees are eligible to participate in the pension plan. All Named Executive Officers participate in the pension plan, as amended. Participants may receive plan benefits as an annuity or as a lump sum.

The following table lists the estimated annual benefits payable at normal retirement age for the Named Executive Officers (other than Messrs. Dillon and Bridges), which are based upon the current qualified pay limits ($205,000 in 2004) projected forward, if such officer elects to receive plan benefits as an annuity. Benefits based upon pay above the qualified pay limits are nonqualified and are paid from the Excess Benefit Plan, discussed below.

~~Index to Financial Statements~~

The following table sets forth information concerning annual benefits payable upon normal retirement at age 65 to TNP Enterprises and TNMP employees under the pre-amendment pension plan, and reflects the “grandfathered” benefit formula for individuals retiring in 2002 with the years of service indicated.

Annual contributions to the pre-amendment pension plan are computed on an actuarial basis and cannot be calculated readily on a per person basis. Benefits for each eligible employee under the old formula are based on his or her years of service computed through the month of his or her retirement, multiplied by a specified percentage of his or her average monthly compensation for each full calendar year of service completed after 1992.

Pension plan benefits are not subject to reduction for Social Security benefits, but are subject to reduction for retirement prior to age 62.

Highly compensated employees whose pensions are subject to being reduced to an amount below what the pension plan otherwise would provide as a result of compliance with Tax Code §§415 and 401(a)(17), and whom the Board of Directors designates as eligible, may also participate in our “Excess Benefit Plan.” Our board of directors has designated 20 TNMP employees as eligible to participate in the Excess Benefit Plan, including the Named Executive Officers and three retired employees now receiving excess benefit payments. Amounts paid as long-term incentive compensation pursuant to the TNP Equity Incentive Plan (which was terminated in 2000) or other plans will be included in the remuneration base for pension and Excess Benefit Plan purposes.

TNP Enterprises and First Choice are also participants in the Pension and Excess Benefit Plans.

Employment Contracts and Termination, Severance and Change of Control and Arrangements

Mr. Chambers.Mr. Chambers is employed pursuant to a one-year employment agreement with us that became effective on April 8, 2003. It provides that Mr. Chambers will receive a base salary of not less than $380,000 and an annual incentive bonus that will be based on the attainment of financial and operational goals to be established.

Mr. Chambers’ agreement also provides that if Mr. Chambers’ employment is terminated for any reason, he (or his estate, in the event of his death) shall be entitled to receive a special lump sum retirement benefit equal to $848,677. If Mr. Chambers’ employment is terminated for Cause, all rights under his employment agreement (other than the special retirement benefits described in the preceding sentence) shall cease and he shall not be entitled to any additional compensation or payments under his employment agreement.

~~Index to Financial Statements~~

Mr. Cheema. We have agreed to provide Mr. Cheema (or his estate, in the event of his death) with a special lump sum retirement benefit equal to $700,000 if his employment agreement with First Choice is terminated for any reason.

Change of Control Agreements. Mr. Forbes and each of the Named Executive Officers currently employed by us have entered into a change of control agreement. Under such agreements, if, within the period beginning 90 days prior to and ending 365 days after a change of control of TNP Enterprises, us or, in the case of Messrs. Chambers, Blanchard, Forbes and Ms. Davis, First Choice, the officer’s employment is terminated without Cause (as the agreements define such term) or the officer resigns following a significant change in duties, responsibilities, authority, title, reporting responsibilities, compensation or benefits, then the officer would become entitled to receive:

If the officer is terminated for Cause, or terminates his or her employment other than for the reasons giving rise in the change of control benefits, the officer will not receive any change in control benefits. In addition, each officer will be entitled to receive the benefits described in paragraphs (b) and (c), above only if the officer executes a release in such form as we require releasing us from any and all further liability in connection with such termination, and such release becomes effective by its terms.

Each agreement shall terminate upon the earliest of (a) the date that all obligations of the parties to the respective agreement have been satisfied; (b) the date, prior to a change of control, that the officer is no longer employed by TNMP; (c) the second anniversary of a change of control; and (d) April 7, 2006, the third anniversary of the effective date of the respective agreements.

~~Index to Financial Statements~~

Our Compensation Committees oversee all executive compensation matters of TNP Enterprises and TNMP. Messrs. Flynn and Lowin are members of the Committee. During 2002, Mr. Geren and Dr. Catacosinos were also members of the Committee.

Employment Agreements. During 2002, the Named Executive Officers of TNMP were compensated in accordance with their respective employment agreements. These employment agreements were in place when the Committee was formed in 2000. Each TNMP employment agreement provided that the officer would continue to perform duties consistent with his or her then–current duties at a minimum level of compensation over the three-year period following the Merger, which expired on April 7, 2003.

Incentive Compensation.A portion of each Named Executive Officer’s compensation under his or her employment agreement consists of an annual incentive bonus. This bonus may range from 0 percent to 37.5 percent of the officer’s base salary, and is based on the attainment of certain pre-established financial and operational goals. It is also subject to the officer’s employment with TNP, TNMP or their respective subsidiaries through the end of the relevant year.

TNMP paid the incentive bonuses for the 2002 performance period in February 2003. The performance measures used were the same measures used in the TNP and TNMP Management Short-Term and Broad-Based Incentive Compensation Plans. The performance measures for the Named Executive Officers other than Mr. Hobbs also included measures used by First Choice in its Management Short-Term and Broad-Based Incentive Compensation Plans. The performance measures include (i) cash flow financial measures for TNMP and First Choice (ii) TNMP operational performance measures of customer satisfaction, system reliability and safety, and (iii) First Choice operational performance measures of customer satisfaction, customer retention, and call center responsiveness, and (iv) measures of performance applicable to different departments of each company. The overall attainment of the performance measures resulted in a composite payout of 128.3 percent of target for TNMP’s transmission and distribution employees, including Mr. Hobbs, or approximately 33.0 percent of their annual base salary; and 88.2 percent of target for persons in TNMP’s shared services organization, including Messrs. Blanchard, Bridges and Ms. Davis, or approximately 25.0 percent of their annual base salary.

The performance measures at TNMP were generally at or above target. Most First Choice performance measures that exceeded the minimum required for a payout with respect to that measure were at or above target. Other measures did not achieve the minimum and no amounts were paid with respect to those measures. The First Choice financial performance measure, First Choice cash flow, required that First Choice’s cash flow exceed a specified amount. The attainment of this financial goal was a prerequisite to any payout with respect to any First Choice goal. First Choice’s original cash flow was below the minimum level originally specified. The original goal had assumed that First Choice would put in place a receivables securitization program to replace TNMP’s factoring arrangement that was terminated early in 2002. Because no such program was implemented during 2002, primarily for reasons beyond the control of First Choice, the Committees approved an adjustment to this goal to permit a payout related to that and other First Choice goals. The Committees also approved an adjustment to First Choice’s operational goal related to call center responsiveness to permit a minimum payout with respect to that goal. The volume of calls to First Choice’s offices and call center were much higher than was anticipated at the time that the goal was set.

In 2002, a portion of TNMP’s matching contribution to the TNMP 401(k) retirement plan for employees was also based on the same financial performance measure used in the TNMP Management Short-Term and Broad-Based Incentive Compensation Plans. The financial performance measure was above its target goal. The Company made an incentive matching contribution to the 401(k) accounts of eligible participants, including executive officers, equal to approximately 50 percent of the amount TNMP matched for each participating TNMP transmission and distribution employee, including Mr. Hobbs, and 39 percent of the total amount that TNMP matched for all other employees, including the other Named Executive Officers, during 2002.

Compensation of TNMP Chairman and Chief Executive Officer.Mr. Chambers’ compensation was as provided in his employment contract, which became effective on April 8, 2001, when he was elected Chairman,

~~Index to Financial Statements~~

President and Chief Executive Officer of TNMP. This agreement is described in this report under “Executive Compensation – Employment Contracts and Termination, Severance and Change of Control Arrangements.”

Internal Revenue Code §162(m).Internal Revenue Code Section 162(m) limits tax deductions for executive compensation to $1 million. There are several exemptions to Section 162(m), including one for qualified performance-based compensation. To be qualified, performance-based compensation must meet various requirements, including shareholder approval. The Committee’s policy with respect to the deductibility limit of Section 162(m) generally is to preserve the federal income tax deductibility of compensation paid when it is appropriate and is in the best interests of TNP Enterprises and its shareholders. However, the Committee reserves the right to authorize the payment of nondeductible compensation if it deems that such action is appropriate.

The Compensation Committee Report on Executive Compensation will not be deemed incorporated by reference by any general statement incorporating this report by reference into any filing under the Securities Act of 1933 or the Securities Exchange Act of 1934, except to the extent that TNP Enterprises or TNMP specifically incorporates the information by reference.

~~Index to Financial Statements~~

The following description is a summary of the material provisions of the Indenture (as defined under the subheading “General”). It does not restate the Indenture in its entirety. We urge you to read the Indenture because it, and not this description, defines your rights as holders of the exchange notes. We have a filed a copy of the Second Supplemental Indenture, under which the existing notes and exchange notes are issued, as Exhibit 4 to our Quarterly Report on Form 10-Q for the quarter ended June 30, 2003. We filed a copy of the base indenture as an exhibit to our Annual Report on Form 10-K for the year ended December 31, 1998.

You can find the definitions of capitalized terms used in this section under the subheading “Definitions” beginning on page 65. As used in this section, the term “Senior Notes” refers to both the existing notes and the exchange notes.

In the exchange offer we will issue up to $250,000,000 of exchange notes in exchange for a like amount of the existing notes under an Indenture, dated as of January 1, 1999 between Texas-New Mexico Power Company and JPMorgan Chase Bank (successor to Chase Bank of Texas, N.A.), as Trustee (the “Trustee”), as amended and supplemented by the First Supplemental Indenture dated as of January 1, 1999 and a Second Supplemental Indenture, dated as of June 1, 2003, between us and the Trustee (the indenture, as supplemented and amended by the First Supplemental Indenture and Second Supplemental Indenture collectively, the “Indenture”). The existing notes, exchange notes and all other debt securities issued under the Indenture, as supplemented from time to time, are collectively referred to herein as the “Senior Debt Securities.” The exchange notes will have substantially identical terms as the existing notes, except that the transfer restrictions and the registration rights relating to the existing notes will not apply to the exchange notes. See “The Exchange Offer—Reasons for the Exchange Offer.”

The Senior Notes will rank without preference or priority among themselves and the other Senior Debt Securities and equally with all of our existing and future unsecured and unsubordinated indebtedness. The Senior Notes will be effectively subordinated to all indebtedness and other liabilities (including guaranteed obligations) of our Subsidiaries. We do not currently have any outstanding indebtedness that ranks senior to the Senior Notes. The terms of a credit facility under which TNP Enterprises is a borrower generally limits the ability of our Subsidiaries to incur additional indebtedness, other than a limited amount of secured indebtedness, a limited amount of indebtedness to finance working capital needs, refinancing indebtedness, and indebtedness owed to another wholly owned subsidiary of TNP Enterprises.

The Senior Notes will be a single, distinct series of Senior Debt Securities. We may from time to time, without the consent of existing holders of the Senior Notes, create and issue an additional principal amount of Senior Notes of the same series and having the same terms and conditions as the Senior Notes in all respects, except for issue date, issue price and, if applicable, the first payment of interest thereon. Additional Senior Notes issued in this manner will be consolidated with and will form a single series with the previous outstanding Senior Notes. The Indenture permits us to issue an unlimited amount of Senior Debt Securities in different series from time to time. The specific terms of each of the series may differ from the Senior Notes. The Indenture does not limit the number of other series of Senior Debt Securities we may issue or the aggregate amount of any particular series. The Indenture does not require that we issue future issues of debt securities under the Indenture. Subject to certain restrictions that are described in “—Restrictions on Liens” and “—Restrictions on Sale and Lease-Back Transactions,” we will be free to employ other indentures or documentation containing provisions different from those included in the Indenture or applicable to one or more series of Senior Debt Securities, in connection with future issues of other debt securities.

The Indenture does not contain any debt covenants or provisions which would afford holders of Senior Notes protection in the event we complete a highly leveraged transaction.

~~Index to Financial Statements~~

be our direct, unsecured obligations,

be initially limited to an aggregate principal amount of $250,000,000, and

mature on June 1, 2008.

begin to accrue on June 10, 2003,

accrue at the annual interest rate stated on the cover page of this prospectus,

be payable semi-annually in cash on May 1 and November 1 in each year, commencing November 1, 2003,

be calculated based on a 360-day year consisting of twelve 30-day months, and

be paid to the person in whose name the Senior Note is registered at the close of business on April 15 and October 15, respectively, whether or not a business day, next preceding such interest payment date.

The principal of (and premium, if any) and interest on the Senior Notes will be payable, and the Senior Notes will be exchangeable and transfers thereof will be registrable, at the Place of Payment, provided that, if the Senior Notes are not Global Securities, at our option, payment of interest with respect to such Senior Notes may be made by check mailed or wire transferred to the address of each Holder of such Senior Notes.

The Senior Notes will be issued in United States dollars in fully registered form, without coupons, in denominations of $1,000 or any integral multiple thereof. No service charge will be made for any transfer or exchange of the Senior Notes, but we may require payment of a sum sufficient to cover any tax or other governmental charge payable in connection with the transfer or exchange of the Senior Notes.

We may redeem the Senior Notes, in whole or in part, at any time prior to May 1, 2005, by paying the Make-Whole Price. The “Make-Whole Price” is an amount equal to the greater of (i) 100% of the principal amount of the Senior Notes and (ii) as determined by a Reference Treasury Dealer appointed by the Trustee after consultation with us (an “Independent Investment Banker”), the sum of the present values of the remaining scheduled payments of principal and interest thereon as if such notes were to be redeemed at the 102.50% of the principal amount of the Senior Notes, which is the Applicable Redemption Price on May 1, 2005, (not including any portion of such payments of interest accrued as of the redemption date) discounted to the redemption date on a semi-annual basis (assuming a 360-day year consisting of twelve 30-day months) at the Adjusted Treasury Rate, plus, in each case, accrued and unpaid interest thereon to, but excluding, the redemption date; provided, however, that installments of interest on the Senior Notes that are due and payable on an interest payment date falling on or prior to the relevant redemption date will be payable to the holders of such exchange notes, registered as such at the close of business on the relevant record date according to the terms and provisions of the Indenture. The following definitions relate to the redemption of the Senior Notes prior to May 1, 2005.

“Adjusted Treasury Rate” means, with respect to any redemption date, the rate per annum equal to the semi-annual equivalent yield to maturity of the Comparable Treasury Issue, calculated using a price for the Comparable Treasury Issue (expressed as a percentage of its principal amount) equal to the Comparable Treasury Price for such redemption date, plus 0.45%.

“Applicable Redemption Price” means the price, stated as a percentage of principal amount of the Senior Notes, at which the Senior Notes may be redeemed on or after May 1, 2005. See “Redemption of the Notes on or after May 1, 2005.”

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“Comparable Treasury Issue” means the United States Treasury security selected by an Independent Investment Banker as having a maturity comparable to the remaining term of the Senior Notes to be redeemed that would be utilized, at the time of selection and in accordance with customary financial practice, in pricing new issues of corporate debt securities having a maturity comparable to the remaining term of such Senior Notes.

“Comparable Treasury Price” means, with respect to any redemption date, (i) the average of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) on the third business day preceding such redemption date, as set forth in the daily statistical release (or any successor release) published by the Federal Reserve Bank of New York and designated “Composite 3:30 p.m. Quotations for U.S. Government Securities,” or (ii) if such release (or any successor release) is not published or does not contain such prices on such business day, (A) the average of the Reference Treasury Dealer Quotations for such redemption date, after excluding the highest and lowest such Reference Treasury Dealer Quotations, or (B) if the Trustee obtains fewer than three such Reference Treasury Dealer Quotations, the average of all such Reference Treasury Dealer Quotations.

“Reference Treasury Dealer” means each of Barclays Capital Inc. and CIBC World Markets Corp., and their respective successors; provided, however, that if any of the foregoing is not a primary U.S. Government securities dealer in New York City (a “Primary Treasury Dealer”), we will appoint another Primary Treasury Dealer for such entity.

“Reference Treasury Dealer Quotations” means, with respect to each Reference Treasury Dealer and any redemption date, the average, as determined by the Trustee, of the bid and asked prices for the Comparable Treasury Issue (expressed in each case as a percentage of its principal amount) quoted in writing to the Trustee by such Reference Treasury Dealer at 5:00 p.m. on the third business day next preceding such redemption date.

On or after May 1, 2005, we may redeem the Senior Notes at our option, in whole or in part, at the Applicable Redemption Price set forth below, plus interest accrued to the redemption date. In addition, on or after May 1, 2005, we will be required to redeem the Senior Notes at the Applicable Redemption Price set forth below, plus interest accrued to the redemption date, if and to the extent we or any of our Subsidiaries receive Securitization Proceeds (a “Mandatory Securitization Redemption”). Holders of Senior Notes will not have the opportunity to choose whether or not their Senior Notes are repurchased in a Mandatory Securitization Redemption. Installments of interest on the Senior Notes that are due and payable on an interest payment date falling on or prior to the relevant redemption date will be payable to the holders of such Senior Notes, registered as such at the close of business on the relevant record date according to the terms and provisions of the Indenture. “Securitization Proceeds” means the proceeds of a securitization transaction in which we, pursuant to authorization from the PUCT, if required by applicable law, or other appropriate governmental authorization, transfer rights or other property to a Person formed as a special purpose entity in conjunction with a financing based on our right to recover “stranded costs” pursuant to the 1999 Restructuring Legislation as described in “Risk Factors—Risks Relating to a Changing Regulatory Environment.”

Prior to undertaking a stranded cost securitization, we will be required to determine the amount of our stranded costs in a stranded cost true-up proceeding before the PUCT, apply for and receive a financing order from the PUCT authorizing the financing, and complete the documentation for the transaction. We expect to make the initial filings in the PUCT proceeding in January 2004, and to apply for a financing order as soon as practicable after

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the PUCT order in the true-up proceeding is administratively final. Under its rules, the PUCT must issue an order in the true-up proceeding no later than 150 days after the filing, unless extended for good cause. A securitization order should be issued no later than 90 days after that application is filed. The PUCT orders in both the true-up proceeding and the financing are subject to appeal, and the timing of the receipt of Securitization Proceeds is uncertain. There can be no assurances that we will be able to complete a stranded cost securitization.

In the event of a partial redemption of the Senior Notes, we will issue new Senior Notes for the unredeemed portion in the name of each Holder of the partially redeemed Senior Notes. If less than all the Senior Notes are to be redeemed, the Senior Notes will be redeemed on a pro rata basis.

We will send each Holder of Senior Notes to be redeemed notice of the redemption by first-class mail, postage prepaid, mailed not less than 30 nor more than 60 days prior to the redemption date.

Unless we default in payment of the redemption price, the portion of Senior Notes called for redemption will no longer accrue interest on and after the redemption date.

We may purchase the Senior Notes in the open market, by tender or by other methods. We may hold these purchased Senior Notes, resell them or give them to the Trustee for cancellation. If applicable, we will comply with the requirements of Rule 14e-1 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”) and other securities laws and regulations in connection with any such purchase. The Senior Notes may be defeased in the manner provided in the Indenture. See “Description of Senior Notes—Discharge; Defeasance.”

Principal of and interest and premium, if any, on the Senior Notes issued in the form of Global Securities will be paid in the manner described under the caption “—Book-Entry Securities.”

Any payment made by us for the payment of principal, interest or premium, if any, on any Senior Note that remains unclaimed for two years after such amount has become due and payable will be repaid to us. The holder of a Senior Note will only be able to look to us for payment.

The Indenture provides that as long as any Senior Debt Securities are Outstanding, we may not, and may not permit any Subsidiary to, incur, issue, assume, guarantee or permit to exist Indebtedness that is secured by any Liens on any of our Property or Property of any of our Subsidiaries, or upon shares of capital stock or evidences of Indebtedness issued by any Subsidiary and owned by us or any Subsidiary, whether we or any of our Subsidiaries, as applicable, owned such Property at the date of the Indenture or acquired such Property thereafter, without making, or causing such Subsidiary to make, effective provision to secure all of the Senior Debt Securities issued under the Indenture and then Outstanding by such Lien, equally and ratably with any and all other Indebtedness thereby secured, so long as such Indebtedness shall be so secured. This restriction will not apply to any Indebtedness that is secured by Liens existing on the date of the Indenture or by any of the following:

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The Indenture provides that notwithstanding the foregoing limitations, we or our Subsidiaries may incur, issue, assume, guarantee or permit to exist Indebtedness secured by Liens without equally and ratably securing the Senior Debt Securities of each series then Outstanding, provided, that at the time of such incurrence, issuance, assumption or guarantee of Indebtedness, after giving effect thereto and to the retirement of any of our Indebtedness

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or Indebtedness of any Subsidiary which is concurrently being retired, the sum of (i) the aggregate amount of all outstanding Indebtedness of us and all of our Subsidiaries secured by Liens which we or a Subsidiary could not have incurred, issued, assumed or guaranteed without equally or ratably securing the Senior Debt Securities of each series then Outstanding, except for the provisions of this paragraph, plus (ii) the Attributable Value of Sale and Leaseback Transactions entered into pursuant to “—Restrictions on Sale and Lease-Back Transactions,” does not at such time exceed the greater of 10% of the Net Tangible Assets or 10% of our Consolidated Capitalization.

The Indenture provides that, so long as any Senior Debt Securities are Outstanding, neither we nor any Subsidiary will enter into any arrangement under which we or a Subsidiary would lease, for a period, including renewals, in excess of three years, any Property which it has sold or transferred or is going to sell or transfer (a “Sale and Leaseback Transaction”) unless either: (a) we or the Subsidiary would, when entering into such arrangement, be entitled, without equally and ratably securing the Securities of each series then Outstanding, to incur, issue, assume or guarantee Indebtedness secured by a Lien on such property pursuant to paragraphs (a) to (k), inclusive of “—Restrictions on Liens”; or (b) we, within 180 days after such sale or transfer, apply to the retirement of our Funded Indebtedness an amount equal to the greater of (i) the net proceeds of the sale of Property sold and leased back pursuant to such arrangement or (ii) the fair market value of the Property so sold and leased back at the time of entering into such arrangement (as determined by any two Officers); provided, that the amount to be applied to the retirement of our Funded Indebtedness shall be reduced by (i) the principal amount of any Senior Debt Securities delivered within 120 days after such sale to the Trustee for retirement and cancellation, and (ii) the principal amount of Funded Indebtedness, other than Senior Debt Securities, voluntarily retired by us within 120 days after such sale. Notwithstanding the foregoing, we and our Subsidiaries, or any of us, may enter into a Sale and Leaseback Transaction which would otherwise be prohibited; provided, that at the time of such transaction, after giving effect thereto, the sum of (i) the aggregate amount of the Attributable Value in respect of all Sale and Leaseback Transactions existing at such time which could not have been entered into except for the provisions of this paragraph plus (ii) the aggregate amount of outstanding Indebtedness secured by Liens in reliance on the last paragraph of “—Restrictions on Liens” of the Indenture does not at the time exceed the greater of 10% of the Net Tangible Assets or 10% of our Consolidated Capitalization. A Sale and Leaseback Transaction shall not be deemed to result in the creation of a Lien.

The Trustee may resign at any time with respect to the Senior Notes or any other series of Senior Debt Securities by giving us written notice thereof. The Trustee may be removed at any time with respect to the Senior Notes or any other series of Senior Debt Securities by the Holders of a majority in aggregate principal amount of the Outstanding Senior Debt Securities of that series, delivered to the Trustee and to us.

If at any time: (i) the Trustee fails to comply with the conflict of interest provisions contained in Section 310(b) of the Trust Indenture Act of 1939, as amended by the Trust Indenture Reform Act of 1990, with respect to the Senior Notes or any other series of Senior Debt Securities after written request therefor by us or by any Holder who has been a Holder of the Senior Notes or a Senior Debt Security of that series for at least six months, (ii) the Trustee ceases to be eligible under the Indenture with respect to the Senior Notes or any other series of Senior Debt Securities and fails to resign after written request therefor by us or by any such Holder, (iii) the Trustee becomes incapable of acting with respect to the Senior Notes or any other series of Senior Debt Securities, or (iv) the Trustee is adjudged a bankrupt or insolvent or a receiver of the Trustee or of its property is appointed or any public officer takes charge or control of the Trustee or of its property or affairs for the purpose of rehabilitation, conservation or liquidation, then, in any such case, (1) we may remove the Trustee, with respect to the Senior Notes or the Senior Debt Securities of another series, or, in the case of clause (iv), with respect to all series, or (2) subject to the Indenture, any Holder who has been a Holder of Senior Notes or Senior Debt Securities of another series for at least six months may, on behalf of itself and all others similarly situated, petition any court of competent jurisdiction for the removal of the Trustee and the appointment of a successor Trustee with respect to the series, or, in the case of clause (iv), with respect to all series.

If the Trustee resigns, is removed or becomes incapable of acting with respect to any series of Senior Debt Securities, or if a vacancy occurs in the office of the Trustee with respect to any series of Senior Debt Securities for

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any cause, we, by a board resolution, will promptly appoint a successor Trustee or Trustees with respect to the Senior Debt Securities of that or those series (it being understood that any such successor Trustee may be appointed with respect to the Senior Debt Securities of one or more or all of such series and that at any time there will be only one Trustee with respect to the Senior Debt Securities of any particular series) and will comply with the applicable provisions of the Indenture. If, within one year after such resignation, removal or incapacity, or the occurrence of such vacancy, a successor Trustee with respect to such series of Senior Debt Securities is appointed by the Holders of a majority in aggregate principal amount of the Outstanding Senior Debt Securities of such series delivered to us and the predecessor Trustee, the successor Trustee so appointed will, forthwith upon its acceptance of such appointment in accordance with the applicable requirements of the Indenture, become the successor Trustee with respect to such series and supersede the successor Trustee appointed by us with respect to such series. If no successor Trustee with respect to such series has been so appointed by us or the Holders of such series and accepted appointment in the manner required by the Indenture, any Holder who has been a Holder of a Senior Debt Security of that series for at least six months may, on behalf of itself and all others similarly situated, petition any court of competent jurisdiction for the appointment of a successor Trustee with respect to such series.

We will give notice of each resignation and each removal of the Trustee with respect to the Senior Debt Securities of any series and each appointment of a successor Trustee with respect to the Senior Debt Securities of any series by mailing written notice of such event by first-class mail, postage prepaid, to the Holders of Senior Debt Securities of that series as their names and addresses appear in the Security Register. Each notice shall include the name of the successor Trustee with respect to the Senior Debt Securities of such series and the address of its Corporate Trust Office.

JPMorgan Chase Bank (as successor to Chase Bank of Texas, N.A.) is the Trustee under the Indenture. The Trustee is not the trustee under any other indenture pursuant to which our securities are outstanding. We maintain banking relationships with the Trustee and with an affiliate of the Trustee in the ordinary course of business. The affiliate of the Trustee is part of a syndicated group of banks that has extended credit to TNP Enterprises under a TNP Enterprises credit facility.

The Indenture defines an “Event of Default” with respect to the Senior Debt Securities of any series, including the Senior Notes, as:

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The Indenture provides that if an Event of Default (other than certain bankruptcy Events of Default) with respect to Senior Debt Securities of any series at the time Outstanding occurs and is continuing, either the Trustee or the Holders of not less than 25% in aggregate Principal amount of the Outstanding Senior Debt Securities of that series may, by notice as provided in the Indenture, declare the aggregate principal amount of all Senior Debt Securities of that series to be due and payable immediately upon notice in writing to us (and to the Trustee if given by Holders). Upon the occurrence of certain bankruptcy Events of Default, such principal and interest shall become immediately payable without any such declaration. Upon certain conditions, however, the Holders of a majority in aggregate principal amount of the Outstanding Senior Debt Securities of that series, by written notice to us and the Trustee, may rescind and annul such declaration and its consequences.

The Indenture provides that the Trustee will, within 90 days after the Trustee has received written notice of a default with respect to Senior Debt Securities of any series at the time Outstanding, give to the Holders of the Outstanding Senior Debt Securities of such series, notice of such default known to it if uncured or not waived, provided that, except in the case of default in the payment of principal of (or premium, if any) or interest on any such Senior Debt Securities, the Trustee will be protected in withholding of such notice if the Trustee in good faith determines that the withholding of such notice is in the interest of the Holders of the Outstanding Senior Debt Securities of such series; and, provided further, that such notice shall not be given until 30 days after the occurrence of a “Default” specified in clause (d) of “Event of Default” above. The term “Default” for the purpose only of this provision means any event that is, or after notice or lapse of time or both would become, an Event of Default.

The Holders of a majority in aggregate principal amount of the outstanding Senior Debt Securities of any series will have the right to direct the time, method and place of conducting any proceeding for any remedy available to the Trustee, or exercising any trust or power conferred on the Trustee, with respect to the Senior Debt Securities of such series; provided that (a) the Trustee will have the right to decline to follow any such direction if the Trustee, being advised by counsel, determines that the action so directed may not lawfully be taken or would conflict with the Indenture; (b) the Trustee will have the right to decline to follow such direction if the Trustee determines that the proceedings so directed would be unjustly prejudicial to the Holders not taking part in such action; (c) such direction will be presented by such Holders to the Trustee in a timely manner; (d) such direction will not be in conflict with any rule of law or with the Indenture; and (e) the Trustee may take any other action deemed proper by the Trustee which is not inconsistent with such direction.

The Indenture includes a covenant that we will file at least annually with the Trustee a certificate of no default, or specifying any default that exists.

will be discharged from our obligations with respect to the Senior Debt Securities (except for certain obligations, including registering the transfer or exchange of the Senior Debt Securities, replacing stolen, lost or mutilated Senior Debt Securities, maintaining paying agencies and holding monies for payment in trust) or

need not comply with certain restrictive covenants of the Indenture (and the occurrence of certain Events of Default with respect to such restrictive covenants),

upon the irrevocable deposit with the Trustee (and in the case of a defeasance, 91 days after such deposit), in trust, of money, or U.S. Government Obligations, or a combination thereof, which through the scheduled payment of

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interest thereon and principal thereof in accordance with their terms will provide money in an amount sufficient to pay all the principal of and interest on the Senior Debt Securities on the date such payments are due in accordance with the terms of the Senior Debt Securities to their stated maturities and any mandatory sinking fund payments applicable to the Senior Debt Securities on the day on which such payments are due and payable in accordance with the Indenture and such Senior Debt Securities. To exercise any such option, we are required to meet certain conditions, including delivering to the Trustee an opinion of counsel to the effect that the deposit and related defeasance would not cause the Holders of the Senior Debt Securities to recognize income, gain or loss for federal income tax purposes as a result of such deposit and defeasance, and will be subject to federal income tax on the same amount, in the same manner and at the same times as would have been the case if such deposit and defeasance were not to occur.

The Indenture permits us and the Trustee to execute supplemental indentures that add, change or eliminate provisions of the Indenture or modify the rights of the Holders of Outstanding Senior Debt Securities. Such execution may be without the consent of the Holders of the Senior Debt Securities in some cases and in others with the consent of the Holders of at least a majority in aggregate principal amount of Outstanding Senior Debt Securities of each series of Senior Debt Securities affected by the supplemental indenture. No such supplemental indenture, however, may, without the consent of the Holder of each Outstanding Senior Debt Security of each series affected thereby:

change the Stated Maturity of any Senior Debt Security,

reduce the principal amount of, the rate of interest on or any premium payable upon redemption of, any Senior Debt Security,

change the place or currency of payment on any Senior Debt Security,

impair the right to institute suit for the enforcement of any payment on or after the Maturity or Stated Maturity thereof,

reduce the stated percentage of Outstanding Senior Debt Securities necessary to modify or amend the Indenture or related documents, or

reduce the percentage of aggregate principal amount of Outstanding Senior Debt Securities necessary for waiver of compliance with certain provisions of the Indenture or for the waiver of certain covenants and defaults.

The Indenture provides that Senior Debt Securities of any series that we or any of our affiliates own shall not be deemed to be Outstanding when determining whether the Holders of the requisite principal amount of Outstanding Senior Debt Securities have given any request, demand, authorization, direction, notice consent or waiver under the Indenture.

The Indenture provides that we may, without the consent of the Holders of any of the Outstanding Senior Debt Securities under the Indenture, consolidate with or merge with or into any other Person, or convey, transfer or lease our properties and assets substantially as an entirety to any Person or group of affiliated Persons, in one transaction or a series of related transactions, provided that:

the successor is a corporation organized and validly existing under the laws of the United States, any state thereof or the District of Columbia;

the successor corporation, if other than TNMP, expressly assumes by a supplemental indenture our obligations on the Senior Debt Securities and under the Indenture;

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immediately after giving effect to the transaction, no Event of Default, and no event which, after notice or lapse of time, or both, would become an Event of Default, shall have occurred and be continuing;

if, as a result of any such transaction, our assets would become subject to a Lien not permitted by the Indenture, the Senior Debt Securities are secured equally and ratably with (or prior to) all Indebtedness secured thereby; and

we have delivered to the Trustee an Officers’ Certificate and an Opinion of Counsel each stating that such consolidation, merger, conveyance, transfer and lease and such supplemental indenture comply with the Indenture and that all conditions precedent therein provided for relating to such transaction have been complied with.

The Indenture does not define the term “substantially as an entirety,” although the term is commonly used in indentures and agreements governed by New York law. Because the term is not specifically defined, and has not been interpreted under New York law to represent a specific quantitative test, holders of Senior Notes may not be able to determine when we have entered into a transaction that conveys, transfers or lease our properties and assets substantially as an entirety. As a result of this uncertainty, it may be difficult for the holders to (a) determine whether our covenant relating to consolidation, merger and sale of assets has been breached, (b) declare an event of default, and (c) exercise their acceleration rights. In addition, there could be a disagreement between us and the holders over whether a specific asset sale or sales triggers a sale of our assets “substantially as an entirety,” If holders of the senior notes elect to exercise their rights under the Indenture and we contested such an election, there could be no assurance as to how a court interpreting New York law would interpret the phrase “substantially as an entirety.”

“Attributable Value” in respect of any Sale and Leaseback Transaction means, as of the time of determination, the lesser of (i) the sale price of the Property so leased multiplied by a fraction the numerator of which is the remaining portion of the base term of the lease included in such Sale and Leaseback Transaction and the denominator of which is the base term of such lease, and (ii) the total obligation (discounted to present value at the rate of interest specified by the terms of such lease) of the lessee for rental payments (other than amounts required to be paid on account of property taxes as well as maintenance, repairs, insurance, water rates and other items which do not constitute payments for property rights) during the remaining portion of the base term of the lease included in such Sale and Leaseback Transaction.

“Company Request” means a written request or order signed in the name of TNMP by any two of the following: its Chairman of the Board, its Vice Chairman of the Board, President or a Vice President, its Treasurer, Assistant Treasurer, its Controller, Assistant Controller, its Secretary or Assistant Secretary, its principal financial officer, its principal accounting officer or any other officer, employee or agent of TNMP duly authorized by a Board Resolution and delivered to the Trustee.

“Consolidated Capitalization” of TNMP means consolidated total assets less consolidated non-interest bearing current liabilities, all as shown by a consolidated balance sheet of TNMP and all Subsidiaries prepared in accordance with generally accepted accounting principles at the date of such balance sheet.

“Funded Indebtedness” means notes, bonds, debentures or other similar evidences of Indebtedness which by its terms matures at or is extendible or renewable at the option of the obligor to a date more than 12 months after the date of the creation of such Indebtedness.

“Global Security” means, with respect to any series of Securities issued hereunder, a Security which is executed by TNMP and authenticated and delivered by the Trustee to the Depositary or pursuant to the Depositary’s instruction, all in accordance with this Indenture and an indenture supplemental hereto, if any, or Board Resolution and pursuant to a Company Request, which shall be registered in the name of the Depositary or its nominee and which shall represent, and shall be denominated in an amount equal to the aggregate principal amount of, all of the Outstanding Securities of such series or any portion thereof, in either case having the same terms, including the same original issue date, date or dates on which principal is due, and interest rate or method of determining interest.

~~Index to Financial Statements~~

“Indebtedness” means, with respect to any Person (without duplication), (a) any liability of such Person (1) for borrowed money or under any reimbursement obligation relating to a letter of credit, financial bond or similar instrument or agreement, (2) evidenced by a bond, note, debenture or similar instrument or agreement (including a purchase money obligation) given in connection with the acquisition of any business, properties or assets of any kind (other than a trade payable or a current liability arising in the ordinary course of business or a performance bond or similar obligation), (3) for the payment of money relating to any obligations under any capital lease of real or personal property or (4) under any agreement or instrument in respect of an interest rate or currency swap, exchange or hedging transaction or other financial derivatives transaction; (b) any liability of others described in the preceding clause (a) that the Person has guaranteed or that is otherwise its legal liability; and (c) any amendment, supplement, modification, deferral, renewal, extension or refunding of any liability of the types referred to in clauses (a) and (b) above. For the purpose of determining any particular amount of Indebtedness under this definition, guarantees of (or obligations with respect to letters of credit or financial bonds supporting) Indebtedness otherwise included in the determination of such amount shall not be included.

“Lien” means, with respect to any Property, any mortgage or deed of trust, pledge, hypothecation, assignment, security interest, lien, encumbrance or other security arrangement of any kind or nature whatsoever on or with respect to such Property (including any conditional sale or other title retention agreement having substantially the same economic effect as any of the foregoing).

“Net Tangible Assets” means the amount shown as total assets on our consolidated balance sheet prepared in accordance with generally accepted accounting principles on the date of such balance sheet, less the following: (i) intangible assets including, but without limitation, such items as goodwill, trademarks, tradenames, patents and unamortized debt discount and expense and other regulatory assets carried as an asset on the balance sheet; and (ii) appropriate adjustments, if any, on account of minority interests.

“Outstanding”, when used with respect to Senior Debt Securities of any series, means, as of the date of determination, all such Senior Debt Securities theretofore authenticated and delivered under the Indenture, except:

“Person” means any individual, corporation, partnership, joint venture, association, company, trust, unincorporated organization or government or any agency or political subdivision thereof.

“Property” of any Person means all such Person’s (i) property and assets and (ii) rights to and interests in all property and assets.

“Subsidiary” means any corporation or other business entity of which we own or control (either directly or through one or more other Subsidiaries) more than 50% of the issued share capital or other ownership interests, in each case having ordinary voting power to elect or appoint directors, managers or trustees of such corporation or other business entity (whether or not capital stock or other ownership interests or any other class or classes shall or might have voting power upon the occurrence of any contingency).

“U.S. Government Obligations” means securities that are (1) direct obligations of the United States of America for the payment of which its full faith and credit is pledged or (2) obligations of a Person controlled or supervised by and acting as an agency or instrumentality of the United States of America the payment of which is

~~Index to Financial Statements~~

unconditionally guaranteed as a full faith and credit obligation by the United States of America, which, in either case, are not callable or redeemable at the option of the issuer thereof or any other Person, and shall also include a depository receipt issued by a bank (as defined in Section 3(a)(2) of the Securities Act), as custodian with respect to any obligation or a specific payment of principal of or interest on any such obligation held by such custodian for the account of the holder of such depository receipt, provided that (except as required by law) such custodian is not authorized to make any deduction from the amount payable to the holder of such depository receipt from any amount received by the custodian in respect of the obligation or the specific payment of principal of or interest on the obligation evidenced by such depository receipt.

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On June 10, 2003, we sold the existing notes in a private offering to Barclays Capital Inc. and CIBC World Markets Corp., collectively referred to as the initial purchasers, pursuant to a purchase agreement, dated June 5, 2003, among the initial purchasers and us. We sold the existing notes to the initial purchasers without registration under the Securities Act in reliance on the exemption provided by Section 4(2) of the Securities Act. The initial purchasers subsequently resold or were permitted to resell the existing notes without registration under the Securities Act to qualified institutional buyers in reliance on Rule 144A under the Securities Act and to certain non-U.S. persons in offshore transactions in reliance on Regulation S under the Securities Act.

In connection with the private offering of the existing notes, on June 10, 2003, we entered into a registration rights agreement with the initial purchasers in which we agreed, among other things, to:

file with the SEC on or before September 8, 2003, a registration statement with respect to a registered offer to exchange the existing notes for the exchange notes;

use our reasonable best efforts to cause the exchange offer registration statement to be declared effective under the Securities Act on or before December 7, 2003;

upon effectiveness of the exchange offer registration statement, offer the exchange notes in exchange for surrender of the existing notes;

keep the exchange offer open for not less than 20 business days (or longer, if required by applicable law), after notice of the exchange offer is mailed to the holders of the existing notes; and

use our reasonable best efforts to consummate the exchange offer within 30 days from the effective date of the exchange offer registration statement (or if such day is not a business day, then the next succeeding business day).

We also agreed, if applicable interpretations of the staff of the SEC do not permit us to effect the exchange offer or if for any other reason we do not consummate the exchange offer by January 6, 2004, to:

file a shelf registration statement covering resales of the existing notes or the exchange notes, as the case may be;

use our reasonable best efforts to cause the shelf registration statement to be declared effective under the Securities Act; and

use our reasonable best efforts to keep the shelf registration statement effective for 24 months from the date the existing notes were issued or until (i) all existing notes or exchange notes registered thereunder are disposed of in accordance therewith or (ii) a subsequent shelf registration statement covering all of the existing notes or exchange notes has been declared effective under the Securities Act.

The exchange offer being made by this prospectus is intended to satisfy our obligations under the registration rights agreement. However, we cannot assure you that, if filed, the exchange offer registration statement will be declared effective, or if declared effective, that we will be able to consummate the exchange offer. You are entitled to receive additional interest on the existing notes or the exchange notes, as the case may be, if:

we fail to file the exchange offer registration statement or any required shelf registration statement within the time period prescribed by the registration rights agreement;

(i) we do not consummate the exchange offer within the time period prescribed by the registration rights agreement; or (ii) the exchange offer registration statement is declared effective and ceases to be effective prior to the consummation of the exchange offer, or (iii) any required shelf registration statement that we file is declared effective and ceases to be effective at any time prior to June 10, 2005.

~~Index to Financial Statements~~

Additional interest will accrue on the principal amount of the existing notes or the exchange notes, as the case may be, over and above the stated interest at a rate of 0.25% per annum for the first 90 days immediately following each violation, such additional interest rate increasing by an additional 0.25% per annum at the beginning of each subsequent 90-day period. Additional interest may not accrue for more than one violation at any time and will not exceed, in the aggregate, 1.0% per annum over and above the stated interest rate. Once we have cured any defaults of our obligations under the registration rights agreement, additional interest on the existing notes or the exchange notes, as the case may be, will cease to accrue.

This description of the registration rights agreement is a summary of its material terms. You should refer to the registration rights agreement for a complete statement of your exchange and registration rights. The registration rights agreement is included as Exhibit 4(d) to the registration statement of which this prospectus is a part.

Based on certain no-action letters issued by the staff of the SEC to third parties in connection with transactions similar to the exchange offer, we believe the you may offer for resale, resell or otherwise transfer any exchange notes without compliance with the registration and prospectus delivery requirements of the Securities Act, unless:

you acquire the exchange notes other than in the ordinary course of your business;

you are participating, intend to participate or have an arrangement with any person to participate, in a distribution of the exchange notes;

you are our “affiliate,” as defined in Rule 405 under the Securities Act; or

you are a broker-dealer that acquired existing notes directly from us.

you will not be able to rely on the interpretations of the staff of the SEC in connection with any offer for resale, resale or other transfer of the exchange notes; and

We are not making this exchange offer to, nor will we accept surrender of existing notes from, you if you live in any state in which this exchange offer would not comply with the applicable securities laws or “blue sky” laws of that state. However, we will use our reasonable best efforts to register or qualify the exchange notes for offer and sale under the securities or blue sky laws of those jurisdictions as any holder of existing notes may reasonably request in writing, subject to certain conditions specified in the registration rights agreement.

Each broker-dealer that receives exchange notes for its own account in exchange for existing notes, where the existing notes were acquired by that broker-dealer as a result of market-making activities or other trading activities, must acknowledge that it will deliver a prospectus in connection with any resale of the exchange notes. See “Plan of Distribution.”

Subject to the terms and conditions described in this prospectus and in the letter of transmittal, we will accept for exchange any existing notes properly tendered and not withdrawn prior to 5:00 p.m. New York City time on the expiration date. After authentication of the exchange notes by the trustee under the indenture governing the existing notes and the exchange notes and promptly after the expiration of the exchange offer, we will issue exchange notes in principal amount equal to the principal amount of existing notes accepted in the exchange offer.

~~Index to Financial Statements~~

Existing notes may be tendered only for exchange notes and only in integral multiples of $1,000. If the exchange offer is terminated, any existing notes tendered for exchange will be promptly returned to you.

The exchange offer is not conditioned upon any minimum aggregate principal amount of existing notes being tendered for exchange.

The form and terms of the exchange notes are identical in all material respects to the form and terms of the existing notes, except that:

the offering of the exchange notes has been registered under the Securities Act;

the exchange notes will not be subject to transfer restrictions; and

the exchange notes will not be entitled to exchange and registration rights.

The exchange notes will be issued under and entitled to the benefits of the indenture governing the existing notes.

As of the date of this prospectus, $250,000,000 in aggregate principal amount of the existing notes is outstanding. This prospectus is being sent to DTC, the sole registered holder of the existing notes and to all persons that we can identify as beneficial owners of the existing notes. There will be no fixed record date for determining registered holders of existing notes entitled to participate in the exchange offer.

We intend to conduct the exchange offer in accordance with the provisions of the registration rights agreement, the applicable requirements of the Securities Act and the rules and regulations of the SEC. Existing notes that are not tendered for exchange in the exchange offer will remain outstanding and continue to accrue interest. These existing notes will be entitled to the rights and benefits such holders have under the indenture and the registration rights agreement.

We will be deemed to have accepted for exchange properly tendered existing notes when we have given oral or written notice of the acceptance to the exchange agent and complied with the applicable provisions of the registration rights agreement. The exchange agent will act as agent of the tendering holders for the purpose of receiving the existing notes from us and delivering exchange notes to such holders.

If you tender existing notes in the exchange offer, you will not be required to pay brokerage commissions or fees or, subject to the letter of transmittal, transfer taxes with respect to the exchange of existing notes. We will pay all charges and expenses, other than certain applicable taxes described below, in connection with the exchange offer. See “— Fees and Expenses” for more details regarding fees and expenses incurred in the exchange offer.

We will return any existing notes that we do not accept for exchange for any reason without expense to their tendering holder promptly after the expiration or termination of the exchange offer.

The exchange offer will expire at 5:00 p.m., New York City time, on , 2003, unless, in our sole discretion, we extend it.

We expressly reserve the right, at any time or various times, to extend the period of time during which the exchange offer is open. We may delay acceptance of any existing notes by giving oral or written notice of such extension to their holders. During any such extensions, all existing notes previously tendered will remain subject to the exchange offer, and we may accept them for exchange.

~~Index to Financial Statements~~

In order to extend the exchange offer, we will notify the exchange agent orally or in writing of any extension. We will notify the registered holders of existing notes of the extension no later than 9:00 a.m., New York City time, on the next business day after the previously scheduled expiration date.

If any of the conditions described below under “—Conditions to the Exchange Offer” have not been satisfied, we reserve the right, in our sole discretion, to:

delay accepting for exchange, or refuse to accept for exchange, any existing notes, provided that we may not delay acceptance of existing notes tendered for exchange subsequent to the expiration of the exchange offer , other than in anticipation of receiving any necessary government approvals,

extend the exchange offer,

terminate the exchange offer, or

amend the terms of the exchange offer.

Any delay in acceptance, extension, termination or amendment will be followed as promptly as practicable by oral or written notice thereof to the registered holders of existing notes. If we amend the exchange offer in a manner that we determine to constitute a material change, we will promptly disclose such amendment in a manner reasonably calculated to inform you of the amendment and we will extend the exchange offer to the extent required by law.

We will not be required to accept for exchange, or to issue exchange notes for any existing notes, if:

the exchange offer, or the making of any exchange by a holder of existing notes would violate applicable law or any applicable interpretation of the SEC staff;

an action or proceeding with respect to the exchange offer has been instituted or threatened in a court or before a government agency or body;

a law, statute or regulation that can reasonably be expected to impair our ability to proceed with the exchange offer has been adopted or enacted;

Similarly, we may terminate the exchange offer as provided in this prospectus before accepting existing notes for exchange in the event of such a potential violation.

These conditions are for our sole benefit, and we may assert them or waive them in whole or in part at any time or at various times in our sole discretion. Our failure at any time to exercise any of these rights will not mean that we have waived our rights. Each such right will be deemed an ongoing right that we may assert at any time or at various times. All such conditions, other than those relating to necessary governmental approvals, will be satisfied or waived prior to the expiration of the exchange offer.

In order to participate in the exchange offer, you must properly tender your existing notes to the exchange agent as described below. It is your responsibility to properly tender your notes. We have the right to waive any defects. However, we are not required to waive defects and are not required to notify you of defects in your exchange.

~~Index to Financial Statements~~

If you have any questions or need help in exchanging your existing notes, please call the exchange agent whose address and phone number appear in the section entitled “The Exchange Agent.”

All of the existing notes were issued in book-entry form, and all of the existing notes are currently represented by global certificates held for the account of DTC. We have confirmed with DTC that the existing notes may be tendered using the Automated Tender Offer Program (“ATOP”) instituted by DTC. The exchange agent will establish an account with respect to the existing notes at DTC for purposes of the exchange offer promptly after the commencement of the exchange offer, and DTC participants may electronically transmit their acceptance of the exchange offer by causing DTC to transfer their existing notes into the exchange agent’s account using the ATOP procedures. In connection with the transfer, DTC will send an “agent’s message” to the exchange agent. The agent’s message will state that DTC has received instructions from the participant to tender existing notes, that the participant agrees to be bound by the terms of the letter of transmittal and that we may enforce such agreement against such participant. Delivery of an agent’s message will also constitute and acknowledgement from the tendering participants that the representations contained in the letter of transmittal are true and correct. See “—Your Representations to Us.”

By using the ATOP procedures to exchange existing notes, you will not be required to deliver a letter of transmittal to the exchange agent. However, you will be bound by its terms just as if you had signed it.

We will determine in our sole discretion all questions as to the validity, form, eligibility, time of receipt, acceptance and withdrawal of tendered existing notes. Our determination will be final and binding. We reserve the absolute right to reject any existing notes not properly tendered or to refuse to accept any existing notes the acceptance of which would, in the opinion of our counsel, be unlawful. We also reserve the absolute right to waive any defect, irregularities or conditions of tender as to particular existing notes, provided that, to the extent we waive a condition of the exchange offer with respect to one tender of existing notes, we will waive that condition for all other tenders as well. Our interpretation of the terms and conditions of the exchange offer, including the instructions in the letter of transmittal, will be final and binding on all parties. Unless waived, all defects or irregularities in connection with tenders of existing notes must be cured within such time as we shall determine. Although we intend to notify you of defects or irregularities with respect to your tender of existing notes, neither we, the exchange agent nor any other person will be under any duty or obligation to do so, and no person will incur any liability for failure to give such notification. Your existing notes will not be validly tendered until you cure any defects or irregularities or we have waived those defects and irregularities. Any existing notes received by the exchange agent that are not properly tendered will be returned to the tendering holder promptly following the expiration date.

purchase or make offers for any existing notes which remain outstanding after the expiration date;

terminate the exchange offer, as set forth in “Conditions to the Exchange Offer;” and

to the extent permitted by applicable law, purchase existing notes during the pendency of the exchange offer in the open market, in privately negotiated transactions or otherwise.

The terms of any of these purchases or offers may differ from the terms of the exchange offer.

In all cases, we will issue exchange notes for existing notes that we have accepted for exchange in the exchange offer only after the exchange agent receives, prior to 5:00 p.m., New York City time, on the expiration date:

a book-entry confirmation of such existing notes into the exchange agent’s account at DTC; and

a properly transmitted agent’s message.

~~Index to Financial Statements~~

The issuance and delivery of exchange notes will occur promptly after the exchange offer.

If we do not accept any tendered existing notes for exchange or if existing notes are submitted for a greater principal amount than the holder desires to exchange, the unaccepted or non-exchanged existing notes will be returned without expense to their tendering holder. Such non-exchanged existing notes will be credited to an account maintained with DTC. These actions will occur promptly after the expiration or termination of the exchange offer.

Your tender of existing notes will constitute a binding agreement between you, us and the exchange agent in accordance with the terms and subject to the conditions set forth in this prospectus and the accompanying letter of transmittal.

By tendering your existing notes and agreeing to be bound by the letter of transmittal, you will represent to us that, among other things:

any exchange notes that you receive will be acquired in the ordinary course of your business;

you are not participating in, do not intend to participate in, and do not have any arrangement or understanding with any person or entity to participate, in the distribution of the exchange notes;

if you are a broker-dealer that will receive exchange notes for your own account in exchange for existing notes, you acquired those existing notes as a result of market-making activities or other trading activities and you will deliver a copy of this prospectus, as required by law, in connection with any resale the exchange notes; and

you are not our “affiliate,” as defined in Rule 405 under the Securities Act

you acquire the exchange notes other than in the ordinary course of your business;

you are participating, intend to participate or have an arrangement with any person to participate, in a distribution of the exchange notes;

you are our “affiliate,” as defined in Rule 405 under the Securities Act; or

you are a broker-dealer that acquired existing notes directly from us;

you will not be able to rely on the interpretations of the staff of the SEC in connection with any offer for resale, resale or other transfer of the exchange notes; and

Except as otherwise provided in this prospectus, you may withdraw your tender of existing notes at any time prior to 5:00 p.m., New York City time, on the expiration date. For a withdrawal to be effective you must comply with the appropriate procedures of DTC’s ATOP system. Any notice of withdrawal must specify the name and number of the account at DTC to be credited with withdrawn existing notes and otherwise comply with the procedures of DTC.

~~Index to Financial Statements~~

We will determine all questions as to the validity, form, eligibility and time of receipt of notice of withdrawal. Our determination shall be final and binding on all parties. We will deem any existing notes so withdrawn not to have been validly tendered for exchange for purposes of the exchange offer.

Any existing notes that have been tendered for exchange but that are not exchanged for any reason will be credited to an account maintained with DTC for the existing notes. This return or crediting will take place promptly after withdrawal, rejection of tender or termination of the exchange offer. You may retender properly withdrawn existing notes by following the procedures described under “-Procedures for Tendering” above at any time on or prior to the expiration date.

We will bear the expenses of soliciting tenders. The principal solicitation is being made by mail; however, we may make additional solicitations by telegraph, telephone, facsimile or in person by our officers and regular employees and those of our affiliates.

We have not retained any dealer-manager in connection with the exchange offer and will not make any payments to brokers, dealers or others soliciting acceptances of the exchange offer. We will, however, pay the exchange agent reasonable and customary fees for its services and reimburse it for its related reasonable out-of-pocket expenses.

We will pay the cash expenses to be incurred in connection with the exchange offer. They include:

We will pay all transfer taxes, if any, applicable to the exchange of existing notes under the exchange offer. The tendering holder, however, will be required to pay any transfer taxes, whether imposed on the registered holder or any other person, if a transfer tax is imposed for any reason other than the exchange of existing notes under the exchange offer.

If you do not exchange your existing notes for exchange notes in the exchange offer, you will remain subject to the restrictions on transfer of existing notes. In general, you may not offer or sell the existing notes unless they are registered under the Securities Act, or if the offer or sale is exempt from the registration under the Securities Act and applicable state securities laws. Except as required by the registration rights agreement, we do not intend to register resales of the existing notes under the Securities Act.

We will record the exchange notes in our accounting records at the same carrying value as the existing notes. This carrying value is the aggregate principal amount of the existing notes less any bond discount, as reflected in our accounting records on the date of exchange. Accordingly, we will not recognize any gain or loss for accounting purposes in connection with the exchange offer.

~~Index to Financial Statements~~

Participation in the exchange offer is voluntary, and you should carefully consider whether to accept. You are urged to consult your financial and tax advisors in making your own decision on what action to take.

We may in the future seek to acquire existing notes in open market or privately negotiated transactions, through subsequent exchange offers or otherwise, to the extent the indenture permits us to do so. We have no present plans to acquire any existing notes that are not tendered in the exchange offer or to file a registration statement to permit resales of any untendered existing notes.

We will, if the Shelf Registration Statement is filed, among other things, provide to each holder of the existing notes or the exchange notes, as the case may be, copies of the prospectus that is a part of the Shelf Registration Statement, notify each holder when the Shelf Registration Statement has become effective and take certain other acts as are required to permit unrestricted resale of the existing notes or exchange notes, as the case may be. A holder selling such existing notes or exchange notes pursuant to the Shelf Registration Statement would generally be required to be named as a selling security holder in the related prospectus and to deliver a prospectus to purchasers, will be subject to certain of the civil liability provisions under the Securities Act in connection with such sales and will be bound by the provisions of the registration rights agreement that are applicable to such holder (including certain indemnification rights and obligations).

The following is a discussion of anticipated material U.S. federal income tax consequences of the ownership and disposition of the exchange notes and the exchange of the existing notes for the exchange notes pursuant to the exchange offer. This summary is based upon laws, regulations, rulings and decisions currently in effect, all of which are subject to change at any time, possibly with retroactive effect. Moreover, it deals only with purchasers who hold notes as “capital assets” within the meaning of Section 1221 of the U.S. Internal Revenue Code of 1986, as amended, and does not purport to deal with persons in special tax situations, such as financial institutions, insurance companies, regulated investment companies, tax-exempt investors, dealers in securities or currencies, partnerships or other pass through entities and the beneficial owners thereof, U.S. expatriates, persons holding notes as a hedge against currency risk or as a position in a “straddle”, “hedge”, “conversion” or another integrated transaction for tax purposes or U.S. Holders, as defined below, whose functional currency is not the U.S. dollar. Further, this discussion does not address the consequences under U.S. federal estate or gift tax laws or the laws of any U.S. state or locality.

You are urged to consult your own tax advisors concerning the consequences, in your particular circumstances, of the ownership and disposition of the exchange notes and the exchange of the existing notes for the exchange notes pursuant to the exchange offer under the U.S. federal tax laws and the laws of any relevant state, local or non-U.S. taxing jurisdiction.

As used in this section, the term “U.S. Holder” means a beneficial owner of notes that is, for U.S. federal income tax purposes:

a citizen or resident of the United States,

a corporation (or other entity classified as a corporation for U.S. Federal income tax purposes) created or organized in or under the laws of the United States or of any political subdivision thereof,

an estate whose income is subject to U.S. federal income tax regardless of its source, or

a trust (x) if, in general, a court within the United States is able to exercise primary jurisdiction over its administration and one or more U.S. persons have authority to control all of its substantial decisions or (y) that has a valid election in effect under applicable U.S. Treasury regulations to be treated as a U.S. person.

As used in this section, the term “non-U.S. Holder” means a beneficial owner of notes that is not a U.S. Holder for U.S. federal income tax purposes. If a partnership holds notes, the tax treatment of a partner will depend

~~Index to Financial Statements~~

on the status of the partner and the activities of the partnership. If you are a partner of a partnership holding notes, you should consult your own tax advisor.

References in this section to “notes” mean any existing notes or exchange notes outstanding at the time discussed.

An exchange of existing notes for exchange notes pursuant to the exchange offer will not be treated as an exchange or other taxable event for United States federal income tax purposes. Accordingly, there will be no United States federal income tax consequences to holders of existing notes who exchange existing notes for exchange notes pursuant to the exchange offer, and such holders will have the same tax basis and holding period in the exchange notes as they had in the existing notes immediately before the exchange.

Interest paid on the notes, including any Additional Interest, should be taxable as ordinary income for U.S. federal income tax purposes when received or accrued by a U.S. Holder in accordance with such U.S. Holder’s method of tax accounting.

Upon the sale, redemption or other taxable disposition of a note, a U.S. Holder should recognize capital gain or loss equal to the difference between the amount realized (excluding any amount attributable to accrued interest, which will be taxable as ordinary interest income as described above, or accrued market discount, which is discussed below) and the U.S. Holder’s tax basis in the notes, which is generally the U.S. Holder’s cost. Such gain or loss will be long-term capital gain or loss if the notes are held for more than one year. The deductibility of capital losses is subject to certain limitations.

On or after May 1, 2005, the notes are mandatorily redeemable to the extent of any Securitization Proceeds received by us. Prior to November 1, 2007, the Applicable Redemption Price exceeds the principal amount of the notes. See “Description of the Senior Notes —Redemption of the Senior Notes on or after May 1, 2005.” Under applicable Treasury Regulations, in determining whether debt instruments are issued with original issue discount (“OID”), an unconditional option held by the issuer to redeem the instruments is ignored if exercise of the option would increase their yield. It is possible that this rule would not apply to a redemption of the notes following a securitization transaction, since such a redemption is mandatory and not an unconditional option held by us. If that were the case, then the notes may be subject to special rules that apply to contingent payment debt instruments. Under those rules, holders would be required to include in interest income amounts in excess of the stated interest rate on the notes, regardless of their method of tax accounting. However, because it is our unconditional option whether to undergo a securitization after appropriate governmental authorization is obtained, and thus redeem all or a portion of the notes with the proceeds thereof, the securitization redemption provisions of the notes should be subject to the rules that apply to issuer call options. Therefore, the redemption provisions of the notes should not be taken into account and the notes should not be treated as issued with OID.

Special rules apply to notes acquired at a premium or market discount, which are discussed below.

If a U.S. Holder purchased notes for an amount in excess of the amount payable at the maturity date of the Notes, the U.S. Holder may elect to amortize such excess as amortizable bond premium over the term of the notes under a yield-to-maturity formula. The election to amortize bond premium must be made with a timely filed federal income tax return for the first taxable year to which the U.S. Holder wishes the election to apply. This election is revocable only with the consent of the Internal Revenue Service and applies to all obligations owned or subsequently acquired by the U.S. Holder. The U.S. Holder’s adjusted tax basis in the notes will be reduced to the extent of the deduction of amortizable bond premium. The amortizable bond premium is treated as an offset to

~~Index to Financial Statements~~

interest income on the notes rather than as a separate deduction item. The rules regarding bond premium are complex and holders should consult their tax advisors.

A U.S. Holder that acquires notes, other than in an original issue, at a market discount (other than market discount that is less than ¼ of 1% of the stated redemption price of the notes at maturity multiplied by the number of remaining complete years to maturity) must include as ordinary income upon a subsequent disposition, redemption or gift of the notes, the lesser of:

the gain realized upon the disposition or redemption or, in the case of a gift, the built-in appreciation in the notes, and

the portion of the market discount which accrued on a straight line basis, or, if the U.S. Holder so elects, on a constant yield basis, while the notes were held by such U.S. Holder.

For these purposes, market discount means the excess, if any, of the stated redemption price at maturity of the notes (i.e., their principal amount) over the U.S. Holder’s tax basis in such notes immediately after their acquisition by the U.S. Holder. A U.S. Holder may elect to include accrued market discount in income currently, which would increase the U.S. Holder’s basis in the notes, rather than upon disposition of the notes. This election once made applies to all market discount obligations acquired on or after the first taxable year to which the election applies, and may not be revoked without the consent of the Internal Revenue Service.

A U.S. Holder of notes acquired at a market discount generally will be required to defer the deduction of a portion of the interest on any indebtedness incurred or maintained to purchase or carry such notes until the market discount is recognized upon a subsequent disposition of such notes. Such a deferral is not required, however, if the U.S. Holder elects to include accrued market discount in income currently. The rules regarding market discount are complex and holders should consult their tax advisors.

Non-exempt U.S. Holders will be subject to information reporting with respect to payments of interest on, and, perhaps, the proceeds of the disposition of, notes. Non-exempt U.S. Holders who are subject to information reporting and who do not provide appropriate information when requested may be subject to backup withholding. U.S. Holders should consult their tax advisors.

In general, payments of interest, including any Additional Interest income, received by a non-U.S. Holder will not be subject to U.S. federal withholding tax, provided that the non-U.S. Holder (a) does not actually or constructively own 10% or more of the total combined voting power of all classes of our stock entitled to vote, (b) is not a controlled foreign corporation that is related to us actually or constructively through stock ownership, and (c) provides, to us or our agent, under penalties of perjury (either directly or through a financial institution that holds the note on behalf of the non-U.S. Holder and that holds customers’ securities in the ordinary course of its trade or business or through an intermediary or other entity as provided in the applicable Treasury regulations) a properly executed Form W-8BEN (or other applicable Form W-8 or substitute form) which sets forth the non-U.S. Holder’s (or, if different, the beneficial owner’s) name and address and certifies, under penalties of perjury, that such holder is not a U.S. Holder.

Payments of interest not exempt from United States federal withholding tax as described above will be subject to withholding tax at the rate of 30% unless the interest received on the note is effectively connected with the conduct by the non-U.S. Holder of a trade or business within the United States (see “Effectively Connected Income” below) or a lower treaty rate applies, and, in either case, the non-U.S. Holder provides us with proper certification as

~~Index to Financial Statements~~

to the holders’ exemption from, or reduced rate of, withholding on Form W-8ECI or W-8BEN, respectively (or other applicable Form W-8 or substitute form).

A non-U.S. Holder generally will not be subject to U.S. federal income tax (and generally no tax will be withheld) with respect to gain realized on the disposition of a note, unless (i) the gain is effectively connected with a U.S. trade or business conducted by the non-U.S. Holder (see “Effectively Connected Income” below) or (ii) the non-U.S. Holder is an individual who is present in the United States for 183 or more days during the taxable year of the disposition and certain other requirements are satisfied.

If interest or other payments received by a non-U.S. Holder with respect to the notes (including proceeds from the disposition of the notes) is effectively connected with the conduct by the non-U.S. Holder of a trade or business within the United States (or the non-U.S. Holder is otherwise subject to U.S. federal income taxation on a net basis with respect to such holder’s ownership of notes), such non-U.S. Holder will generally be subject to the rules described above under “U.S. Holders” (subject to any modification provided under an applicable income tax treaty). Non-U.S. Holders that are corporations may also be subject to the U.S. “branch profits tax” at a rate of 30%, or a lower rate provided by an applicable income tax treaty.

Interest paid to non-U.S. Holders will be reported on IRS Form 1042-S, which is filed with the Internal Revenue Service and sent to non-U.S. Holders. If the notes are held by a non-U.S. Holder through a non-U.S., and non-U.S. related, broker or financial institution, backup withholding generally would not be required. Backup withholding may apply if the notes are held by a non-U.S. Holder through a U.S., or U.S. related, broker or financial institution and the non-U.S. Holder fails to provide appropriate information. Non-U.S. Holders should consult their tax advisors.

Based on interpretations by the staff of the SEC in no action letters issued to third parties, we believe that you may transfer exchange notes issued in the exchange offer in exchange for the existing notes if:

you acquire the exchange notes in the ordinary course of your business; and

you are not participating in, and do not intend to participate in, and have no arrangement or understanding with any person to participate in, a distribution of the exchange notes.

our “affiliate” within the meaning of Rule 405 under the Securities Act; or

a broker-dealer that acquired existing notes directly from us.

Each broker-dealer that receives exchange notes for its own account pursuant to the exchange offer must acknowledge that it will deliver a prospectus in connection with any resale of the exchange notes. To date, the staff of the SEC has taken the position in no action letters issued to third parties that broker-dealers may fulfill their prospectus delivery requirements with respect to transactions involving an exchange of securities such as this exchange offer, other than a resale of an unsold allotment from the original sale of the existing notes, with the prospectus contained in this registration statement. This prospectus, as it may be amended or supplemented from time to time, may be used by a broker-dealer in connection with resales of exchange notes received in exchange for existing notes where such existing notes were acquired as a result of market-making activities or other trading activities. We have agreed that, for a period of up to 180 days after the effective date of the registration statement of which this prospectus is a part, we will make this prospectus, as amended or supplemented, available to any broker-dealer for use in connection with any resale. In addition, until such date, all broker-dealers effecting transactions in exchange notes may be required to deliver a prospectus.

~~Index to Financial Statements~~

We will not receive any proceeds from any sale of exchange notes by broker-dealers. Exchange notes received by broker-dealers for their own account pursuant to the exchange offer may be sold from time to time in one or more transactions:

in the over-the-counter market;

in negotiated transactions;

through the writing of options on exchange notes or a combination of these methods of resale;

at market prices prevailing at the time of resale; and

at prices related to such prevailing market prices or negotiated prices.

Any resale may be made directly to purchasers or to or through brokers or dealers who may receive compensation in the form of commissions or concessions from any broker-dealer and/or the purchasers of any exchange notes. Any broker-dealer that resells exchange notes that it received for its own account pursuant to the exchange offer and any broker or dealer that participates in a distribution of the exchange notes may be deemed to be an “underwriter” within the meaning of the Securities Act and any profit from any resale of the exchange notes and any commissions or concessions received by any of these persons may be deemed to be underwriting compensation under the Securities Act. The letter of transmittal states that by acknowledging that it will deliver and by delivering a prospectus, a broker-dealer will not be deemed to admit that it is an “underwriter” within the meaning of the Securities Act.

For a period of 180 days after the effective date of the registration statement of which this prospectus is a part, we will promptly send additional copies of this prospectus and any amendment or supplement to this prospectus to any broker-dealer that requests such documents in the letter of transmittal. We have agreed to pay all expenses incident to the exchange offer (including the expenses of one counsel for the holders of the existing notes) other than commissions or concessions of any broker-dealers and will indemnify the holders of the existing notes (including any broker-dealers) against certain liabilities, including liabilities under the Securities Act.

The validity and enforceability of the exchange notes being offered hereby will be passed upon for us by Kramer Levin Naftalis & Frankel LLP, New York, New York.

Our consolidated balance sheets and consolidated statements of capitalization as of December 31, 2002 and 2001, and the related consolidated statements of income, common shareholder’s equity, and cash flows for each of the three years in the period ended December 31, 2002 included herein have been audited by Deloitte & Touche LLP, independent auditors, as stated in their report appearing herein (which report expresses an unqualified opinion and includes an explanatory paragraph referring to our change in our method of accounting for major maintenance costs in 2001), and have been so included in reliance upon the report of such firm given upon their authority as experts in accounting and auditing.

This prospectus includes “forward-looking statements.” Forward-looking statements include, without limitation, any statement that may predict, forecast, indicate or imply future results, performance or achievements, and may contain the words “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “project,” “will be,” “will likely continue,” “will likely result,” or words or phrases of similar meaning including, among other things, statements concerning:

Changes in laws or regulations affecting our business in the states that we serve

Results of regulatory proceedings affecting our operations and the establishment of our stranded costs

Our ability to recover stranded costs

The ability of First Choice to attract additional customers and retain existing customers

~~Index to Financial Statements~~

Changes in laws and regulations to which we are subject, other external factors over which we have no control, such as wholesale prices of electricity, natural gas, and financial markets

Expansion and other growth opportunities arising from growth in population and business expansion in our service areas

The effect of accounting policies issued periodically by accounting standard-setting bodies

Other factors described from time to time in our reports filed with the SEC

Forward-looking statements involve risks and uncertainties, including, but not limited to, economic, competitive, governmental and technological factors outside of our control, that may cause actual results to differ materially from the forward-looking statements. These risks and uncertainties may include those discussed under the heading “Risk Factors.” We operate in a changing environment in which new risk factors can emerge from time to time. It is not possible for management to predict all of these risks, nor can it assess the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in forward-looking statements. Given these risks and uncertainties, readers are cautioned not to place undue reliance on forward-looking statements.

We have filed a registration statement (which term includes any amendments to the registration statement) on Form S-4 with the Securities and Exchange Commission, or the SEC, under the Securities Act of 1933, as amended, covering the exchange notes to be issued in the exchange offer. This prospectus, which constitutes a part of the registration statement, does not contain all of the information set forth in the registration statement and the exhibits thereto, to which reference is hereby made. Each statement in this prospectus referring to a document filed as an exhibit to the registration statement is a statement of certain portions of such document. You should refer to the referenced document for a complete statement of its terms and conditions.

Our parent company, TNP Enterprises, of which we are a wholly-owned subsidiary, and we have elected to file joint annual, quarterly and current reports under the Exchange Act with the SEC. Our SEC filings are available to the public over the Internet at the SEC’s website at http://www.sec.gov. You may also read and copy any document we file at the SEC’s Public Reference Room at 450 Fifth Street, N.W., Washington, D.C. 20549. Information on the operation of the Public Reference Room can be obtained by calling the SEC at 1-800-SEC-0330. You may request a copy of our SEC filings at no cost, by writing or telephoning us at: Corporate Secretary, Texas-New Mexico Power Company, 4100 International Plaza, Fort Worth, Texas 76109, (817) 731-0099. Our SEC filings are available for informational purposes only. We are not incorporating by reference information from our SEC filings into this prospectus.

You may also find information about us on the Internet at http://www.tnpe.com. Information on the TNP Enterprises website is not a part of this prospectus.

This prospectus is part of a registration statement we filed with the Securities and Exchange Commission. In making your investment decision, you should rely only on the information contained in this prospectus and the accompanying letter of transmittal. We have not authorized anyone to provide you with any other information. If you receive any unauthorized information, you must not rely on it. We are not making an offer to sell these securities in any state where the offer is not permitted. You should not assume that the information contained in this prospectus is accurate as of any date other than the date on the front cover of this prospectus.

~~Index to Financial Statements~~

We have audited the accompanying consolidated balance sheets and consolidated statements of capitalization of Texas-New Mexico Power Company and subsidiaries (the Company) as of December 31, 2002 and 2001, and the related consolidated statements of income, cash flows and common shareholder’s equity 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, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of Texas-New Mexico Power Company and subsidiaries at December 31, 2002 and 2001, and the results of their operations and their cash flows for each of the three years in the period ended December 31, 2002, in conformity with accounting principles generally accepted in the United States of America.

As discussed in Note 3 to the consolidated financial statements, the Company changed its method of accounting for major maintenance costs in 2001.

~~Index to Financial Statements~~

The accompanying notes are an integral part of these consolidated financial statements.

~~Index to Financial Statements~~

The accompanying notes are an integral part of these consolidated financial statements.

~~Index to Financial Statements~~

The accompanying notes are an integral part of these consolidated financial statements.

~~Index to Financial Statements~~

The accompanying notes are an integral part of these consolidated financial statements.

~~Index to Financial Statements~~

The accompanying notes are an integral part of these consolidated financial statements.

~~Index to Financial Statements~~

General Information. The consolidated financial statements of TNMP and subsidiaries include the accounts of TNMP and its wholly owned subsidiary, Texas Generating Company (TGC). All intercompany transactions and balances have been eliminated in consolidation.

Retail competition began in Texas under the provisions of the 1999 Restructuring Legislation on January 1, 2002. In accordance with the 1999 Restructuring Legislation, TNMP separated its Texas utility operations into three components: First Choice, TGC and TNMP. First Choice became the retail electric provider and assumed the activities related to the sale of electricity to retail customers in Texas. TGC became the unregulated entity performing the generation activities. In October 2002, TNMP sold TNP One, TGC’s primary asset. TNMP’s remaining Texas operations consist of the regulated transmission and distribution business. In New Mexico, TNMP continues to provide integrated electricity services under traditional cost-of-service rate regulation. Those services include transmitting, distributing, purchasing and selling electricity to its New Mexico customers. TNMP is subject to the Public Utility Commission of Texas (PUCT) and New Mexico Public Regulation Commission (NMPRC) regulation. Some of TNMP’s activities, including the issuance of securities, are subject to FERC regulation, and its accounting records are maintained in accordance with FERC’s Uniform System of Accounts.

The use of estimates is required to prepare TNMP’s consolidated financial statements in conformity with generally accepted accounting principles. Management believes that estimates are essential and will not materially differ from actual results. However, adjustments may be necessary in the future to the extent that future estimates or actual results are different from the estimates used in the 2002 financial statements.

Accounting for the Effects of Regulation. TNMP applies the provisions of Statement of Financial Accounting Standards (SFAS) 71, “Accounting for the Effects of Certain Types of Regulation,” to its transmission and distribution operations in Texas and New Mexico. TNMP discontinued the application of SFAS 71 to the generation/power supply portions of its operations in Texas as a result of the passage of the 1999 Restructuring Legislation.

The 1999 Restructuring Legislation provides for recovery of “stranded costs,” the difference between the regulatory value of TNMP’s investments in generation assets and the market price for energy in a competitive market. Any such stranded costs would be recoverable from TNMP’s Texas transmission and distribution customers. See Note 5 to these consolidated financial statements for additional discussion of TNMP’s stranded costs.

Utility Plant. TNMP’s utility plant is stated at the historical cost of construction, which includes labor, materials, indirect charges for such items as engineering and administrative costs, and Allowance for Funds Used During Construction (AFUDC) or capitalized interest. Property repairs and replacement of minor items are charged to operating expenses, while replacements of units of property are capitalized to utility plant.

AFUDC is a non-cash item designed to enable a utility to capitalize financing costs during periods of construction of property subject to rate regulation. Established regulatory practices enable TNMP to recover these costs from customers. The composite rate used for AFUDC was 7.9 percent in 2002, 9.0 percent in 2001, and 9.6 percent in 2000. AFUDC is applied to construction expenditures for the portion of its business that is accounted for under SFAS 71.

The costs of depreciable units of plant retired or disposed of in the normal course of business are eliminated from utility plant accounts and such costs plus removal expenses less salvage are charged to accumulated depreciation. When complete operating units are disposed of, appropriate adjustments are made to accumulated depreciation, and the resulting gains or losses, if any, are recognized.

Depreciation is provided on a straight-line method based on the estimated lives of the properties as indicated by periodic depreciation studies. A portion of depreciation of transportation equipment used in construction is charged to utility plant accounts in accordance with the equipment’s use. Depreciation as a percentage of average depreciable cost was 3.7 percent, 3.2 percent, and 3.2 percent in 2002, 2001, and 2000, respectively.

Cash Equivalents. Investments in highly liquid debt instruments with maturities of three months or less when purchased are considered cash equivalents.

~~Index to Financial Statements~~

Customer Receivables and Operating Revenues. TNMP accrues estimated revenues for electricity delivered from the latest billing date to the end of the accounting period. Prior to February 2002, TNMP, under a factoring arrangement with an unaffiliated company, sold its customer receivables on a nonrecourse basis. Amounts estimated to have been delivered, but remaining unbilled, were also sold in connection with this agreement. The factoring arrangement was terminated in February 2002, as discussed in Note 8 to these consolidated financial statements.

Purchased Power and Fuel Costs. Effective January 1, 2002, First Choice assumed the energy supply activities related to the sale of electricity to retail customers in Texas. The 1999 Restructuring Legislation created a competitive retail electricity market in Texas and contains no provisions for the specific recovery of fuel and purchased power costs, although First Choice can request that the PUCT change the price-to-beat twice a year to recognize changes in natural gas prices.

In New Mexico, TNMP recovers all purchased power costs through the fuel and purchased power adjustment clause authorized by the NMPRC. The purchased power recovery factor changes monthly to reflect over-collections or under-collections of purchased power costs.

Deferred Charges. Costs incurred in issuing long-term debt are deferred and amortized on a straight-line basis over the lives of the respective issues.

Included in deferred charges are other assets that are expected to benefit future periods and certain costs that are deferred for ratemaking purposes and amortized over periods allowed by regulatory authorities.

Income Taxes. TNP Enterprises, Inc. (TNP) files a consolidated federal income tax return that includes its subsidiaries, including First Choice, and the consolidated operations of TNMP. The amounts of income taxes recognized in TNMP’s accompanying consolidated financial statements were computed as if TNMP and its subsidiaries filed a separate consolidated federal income tax return.

Investment Tax Credit (ITC) amounts utilized in the federal income tax return are generally deferred and amortized to earnings ratably over the estimated service lives of the related assets.

Other Comprehensive Income. Other Comprehensive Income includes unrealized gains and losses related to derivative transactions designated as cash flow hedges and minimum pension liabilities recorded under the provisions of SFAS No. 87, “Employers Accounting for Pensions.”

The components of Other Comprehensive Income for the year ended December 31, 2002, were as follows:

For the year ended December 31, 2001, TNMP’s other comprehensive income included ($0.5) million related to the minimum pension liability. The minimum pension liability was ($0.8) million and related income taxes were $0.3 million.

Derivative Instruments. TNMP may enter into derivative instruments, including options and swaps, to manage risks related to changes in interest rates and commodity prices. TNMP adopted SFAS No.133, “Accounting for Derivative Instruments and Hedging Activities,” as extended and amended, on January 1, 2001. The adoption of SFAS 133 had no impact on the financial position, results of operations or cash flows of TNMP. SFAS 133 requires that TNMP record derivatives on the balance sheet at their fair value. Changes in the fair value of derivatives are recorded in earnings or other comprehensive income depending upon the use of the derivative and whether the derivative qualifies for hedge accounting.

Fair Values of Financial Instruments. Fair values of cash equivalents and customer receivables approximated the carrying amounts because of the short maturities of those instruments.

~~Index to Financial Statements~~

The estimated fair value of long-term debt was based on quoted market prices of the same or similar issues. The estimated fair values of TNMP’s financial instruments are as follows:

Reclassification. Certain items in 2000 and 2001 were reclassified to conform to the 2002 presentation.

Retail Competition.Retail competition began under the provisions of the 1999 Restructuring Legislation on January 1, 2002. Prior to January 1, 2002, TNMP was a fully integrated utility that provided electricity services to its customers. These services consisted of generating, purchasing, transmitting, distributing, and selling electricity to its customers. On January 1, 2002, in accordance with the 1999 Restructuring Legislation, TNMP separated its Texas utility operations into three components. First Choice, TNMP’s affiliated retail electric provider, assumed the activities related to the sale of electricity to retail customers in Texas, TGC became the unregulated entity performing generation activities and TNMP continues to operate its regulated transmission and distribution business in Texas. Accordingly, on January 1, 2002, TNMP transferred net assets to First Choice and TGC. First Choice received equity and net assets of $24.8 million. The net assets consisted primarily of $23.0 million notes receivable from TNMP and field office buildings. The notes receivable pertained to cash to be collected by TNMP for customer account receivables after January 1, 2002. TGC received net assets of $98.6 million, and equity and long-term debt of $73.9 million and $24.7 million, respectively. The net assets pertained primarily to the net book value of TNP One, the generating plant. On December 31, 2001, TNMP had equity and debt ratios of 49.6 percent and 50.4 percent, respectively. On January 1, 2002, after the separation of activities, TNMP’s regulated Texas transmission and distribution operations had equity and debt ratios of 40 percent and 60 percent, respectively, in accordance with a PUCT order. TNMP, First Choice, and TGC are affiliated companies under the common ownership of TNP Enterprises. The operations of First Choice are included in the consolidated financial statements of TNP Enterprises and the operations of TGC are included in the consolidated financial statements of both TNP Enterprises and TNMP.

First Choice must offer former TNMP customers whose loads are less than 1 megawatt a regulated price, commonly called the “price-to-beat.” The price-to-beat will be offered through December 31, 2006, and First Choice cannot offer former TNMP customers any other rate before the loss of 40 percent of its price-to-beat customers or January 1, 2005, whichever occurs first.

The beginning of retail competition affected the methods by which companies recover their purchased power and fuel costs. Prior to December 31, 2001, TNMP recovered fuel and the energy-related portion of purchased power costs from customers through the fuel adjustment clause authorized by the PUCT. The demand-related portion of purchased power was recovered through base rates and, unlike the fuel and energy-related portion, was not subject to adjustment or future reconciliation. Effective January 1, 2002, First Choice assumed the energy supply activities related to the sale of electricity to retail customers in Texas. The 1999 Restructuring Legislation created a competitive retail electricity market in Texas and contains no provisions for the specific recovery of fuel and purchased power costs, although First Choice can request that the PUCT change the price-to-beat twice a year to recognize changes in natural gas prices. The rates charged to new customers acquired by First Choice outside of TNMP’s service territory are not regulated by the PUCT, but are negotiated with each customer. As a result, changes in fuel and purchased power costs will affect First Choice’s operating results.

Final Fuel Reconciliation. As of December 31, 2002, TNMP had an over-recovered balance of fuel and energy-related purchased power costs of $23.7 million. TNMP will carry its over-recovered balance of fuel and energy related purchased power costs to the 2003 final fuel reconciliation. This proceeding will reconcile fuel and energy-related purchased power costs incurred between January 1, 2000, and December 31, 2001, in accordance with the provisions of the 1999 Restructuring Legislation. TNMP’s over-recovered balance of fuel and energy-related purchased power costs from the final fuel reconciliation will be included in the true-up of stranded costs that will occur in 2004. Subject to the results of the final fuel reconciliation, any over-recovered balance may reduce the amount of stranded costs TNMP would be entitled to recover from its transmission and

~~Index to Financial Statements~~

distribution customers. See Note 5 to these consolidated financial statements for additional discussion of TNMP’s stranded costs.

Clawback. The 1999 Restructuring Legislation includes a provision, commonly known as the “clawback” that would require First Choice to credit TNMP the difference between the price-to-beat and the market price of electricity during the years 2002 and 2003. TNMP will include the credit, if any, in the true-up proceeding that will occur in 2004. The maximum credit to TNMP is limited to $150 multiplied by the difference between the number of First Choice price-to-beat customers and the number of First Choice competitively acquired residential and small commercial customers as of January 1, 2004. Based on current assumptions, First Choice estimates that its clawback liability will be $12.7 million. Accordingly First Choice recorded a pre-tax reserve of $12.7 million in the fourth quarter of 2002. To the extent that acquisition of competitive customers and loss of price-to-beat customers differs from current projections, an adjustment to the clawback liability could be required. First Choice estimates that significant variations from its current projections could increase its clawback liability by an additional $4.9 million.

2001 Excess Earnings. In March 2002, TNMP filed its Annual Report with the PUCT. The Annual Report detailed TNMP’s calculation of excess earnings under the provisions of the 1999 Restructuring Legislation. The Annual Report showed that TNMP had no excess earnings for the year ended December 31, 2001, and, in fact, reported a deficiency of $3.1 million. Accordingly, TNMP’s financial results for the twelve months ended December 31, 2002, reflect the reversal of $0.7 million of excess earnings that had been estimated and accrued as of December 31, 2001.

The $3.1 million deficiency shown in TNMP’s Annual Report is attributable to payments of $3.6 million that TNMP made in 2001 to the System Benefit Fund mandated by the 1999 Restructuring Legislation. The PUCT has concluded that utilities that do not have sufficient earnings to cover their System Benefit Fund payments may petition the PUCT for relief. Accordingly, TNMP filed a petition in November 2002 asking the PUCT to allow TNMP to establish a regulatory asset of $3.1 million, the amount of its 2001 Annual Report earnings deficiency that is attributable to System Benefit Fund payments. The petition has been referred to the State Office of Administrative Hearings, and TNMP expects that a hearing on the merits of the petition will occur either late in the first quarter of 2003, or during the second quarter of 2003.

Merger Commitments. As conditions for approval of the acquisition in April 2000 of our parent, TNP Enterprises, by ST Acquisition Corp. (the “Merger”), TNMP made a number of commitments to both the PUCT and NMPRC. The commitments cover a wide range of financial, operational, electric reliability, and other standards that TNMP agreed to honor. TNMP made 55 commitments in New Mexico and Texas, of which 47 are currently in effect. TNMP monitors compliance on a monthly basis and could be subject to financial penalties for non-compliance with certain commitments. During the years ended December 31, 2002 and 2001, TNMP was not in compliance with certain commitments regarding electric reliability standards in Texas. TNMP estimates that penalties for non-compliance with these commitments in 2002 and 2001 will be approximately $0.1 million and $0.1 million, respectively.

In July 2002, FERC issued a Notice of Proposed Rulemaking regarding Standard Market Design. The goal of the proposed rulemaking is to create a standardized design for the wholesale transmission service market. The proposed rulemaking creates a schedule that would result in the provisions of the proposed rule becoming effective at various times in 2003 and 2004. TNMP will monitor the development of the proposed rule to assess the proposed rule’s effects on TNMP’s cost of providing transmission service in New Mexico.

Prior to January 1, 2001, TNMP had deferred the costs of major maintenance projects and amortized those costs to expense over periods ranging from three to seven years. Effective January 1, 2001, TNMP began charging the costs of major maintenance projects to expense as incurred, and wrote off the balance of previously deferred major maintenance costs. TNMP believes that expensing major maintenance costs is preferable to deferring those costs because those costs do not result in the acquisition or replacement of units of property.

The change in accounting for major maintenance costs reduced pre-tax net income for the year ended December 31, 2001, by $1.9 million ($1.2 million after tax). Had this new accounting method been in effect during prior periods, income before the cumulative effect of the change in accounting would not have been materially different from that shown in the accompanying consolidated statements of income.

~~Index to Financial Statements~~

TNMP adopted SFAS No. 143, “Accounting for Asset Retirement Obligations,” on January 1, 2003. The adoption had no impact on the financial position, results of operations, or cash flows of TNMP. As a result of the adoption of SFAS 143, TNMP identified costs recorded in accumulated depreciation related to inclusion of removal costs of utility plant in TNMP’s rates by the PUCT and NMPRC. Such costs do not arise from legal obligations. Rather, they represent long-standing regulatory policy to include charges for removal costs of utility plant in accumulated depreciation. As of December 31, 2002 and 2001, $35.8 million and $33.8 million, respectively, of estimated utility plant removal costs were included in accumulated depreciation.

SFAS 143 requires entities to record the fair value of a liability for an asset retirement obligation in the period in which it is incurred, and capitalize a cost by increasing the carrying amount of the related long-lived asset. Over time, the liability is accreted to its fair value each period, and the capitalized cost is depreciated over the useful life of the related asset. As discussed in Note 5 to these consolidated financial statements, TNMP sold TNP One, its sole generating facility. As a result of the sale, TNMP does not have significant asset retirement obligations that would be subject to the provisions of SFAS 143.

TNMP adopted SFAS No. 144, “Accounting for the Impairment of Long-Lived Assets,” during the fourth quarter of 2001. SFAS 144 establishes a single accounting model for long-lived assets to be disposed of by sale. SFAS 144 requires entities to measure long-lived assets held for sale at the lower of the asset’s carrying amount or fair value less cost to sell and to cease depreciation. The statement also resolved a number of implementation issues related to long-lived assets held for sale. The adoption of SFAS 144 did not have a material effect on the results of operations or financial condition of TNMP. Details regarding the adoption of SFAS 144 can be found in Note 5 to these consolidated financial statements.

In the fourth quarter of 2002, the FASB issued Interpretation No. 45, “Guarantors Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness of Others”. FIN 45 elaborates on the disclosures to be made by a guarantor in its interim and annual financial statements about its obligations under certain guarantees that it has issued. It also clarifies that a guarantor is required to recognize, at the inception of a guarantee, a liability for the fair value of the obligation undertaken in issuing the guarantee.

TNMP and First Choice each guarantee the other entity’s borrowings and issuances of letters of credit under the TNMP/First Choice Credit Facility. TNMP also guarantees First Choice’s performance under the power supply contract with Constellation. The provisions of FIN 45 related to recognizing a liability at inception for the fair value of the guarantor’s obligation do not apply to these guarantees. However, the disclosure requirements do apply, and those requirements became effective for TNMP as of December 31, 2002. Disclosures regarding the guarantees of TNMP and First Choice are included in Note 8 to these consolidated financial statements.

Consolidation of Variable Interest Entities. In January 2003, the FASB issued Interpretation No. 46, “Consolidation of Variable Interest Entities”. FIN 46 addresses the nature of variable interest entities, and specifies the conditions under which such variable interest entities shall be included in the consolidated statements of a business enterprise. FIN 46 becomes effective immediately for variable interest entities created after January 31, 2003. The effective date for variable interests acquired prior to February 1, 2003 is the first fiscal year or interim period beginning after June 15, 2003. As of December 31, 2002, TNMP does not have variable interests that would be subject to the provisions of FIN 46.

TNMP adopted SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities,” as extended and amended, effective January 1, 2001.

Normal Purchases and Sales.In the normal course of business, TNMP enters into commodity contracts, which include “swing” components for additional purchases or sales of electricity, in order to meet customer requirements. In December 2001, the FASB defined criteria by which option-type and forward contracts for electricity could qualify for the normal purchase and sales exception provided by SFAS 133. Based on the FASB’s guidance, the management of TNMP has determined that its contracts for electricity qualify for the normal purchases and sales exception. Accordingly, TNMP does not account for its electricity contracts as derivatives.

Hedging Activities. TNMP may enter into derivative instruments, including options and swaps, to manage risks related to changes in interest rates and commodity prices. At the inception of any such transactions, TNMP documents relationships

~~Index to Financial Statements~~

between the hedging instruments and the items being hedged. The documentation includes the strategy that supports executing the specific transaction.

In October 2002, TNMP entered into interest rate swap transactions designed to manage interest rate risk associated with the TNMP/First Choice Credit Facility. TNMP executed two transactions, each with a notional amount of $75 million. Both transactions terminate in October 2004. Under the terms of the swaps, TNMP pays fixed rates of 2.4 percent and 2.5 percent and receives variable rates that are currently set at approximately 1.4 percent.

The interest rate swaps were designated as cash flow hedges. The swaps were highly effective in offsetting future cash flow volatility caused by changes in interest rates. As of December 31, 2002, TNMP had recorded unrealized after-tax losses of $1.2 million in other comprehensive income. Over the next twelve months TNMP anticipates that $0.9 million of unrealized after-tax losses will be reclassified from other comprehensive income to interest expense. The estimated amounts to be reclassified represent the earnings volatility that is avoided by using the interest rate swaps.

On October 23, 2002, TNMP received the final regulatory approval necessary to complete the sale of TNP One to Sempra Energy Resources, the power generation subsidiary of Sempra Energy. On October 31, 2002, Sempra Energy Resources purchased TNP One from TNMP. The sale completed a process that TNMP started in response to the 1999 Restructuring Legislation, which required electric utilities to separate their power generation business activities from the regulated transmission and distribution business. The 1999 Restructuring Legislation also established various methods for quantifying stranded costs, one of which was the sale of generation plants.

Sempra Energy Resources paid TNMP $120 million for TNP One. Costs of the sale were $2.5 million, including a payment of $1.3 million to Laurel Hill Capital Partners, a related party, for financial advisory services. TNMP used the net proceeds to retire $33.1 million of debt outstanding under the TNMP/First Choice Credit Facility and pay a dividend to TNP of $84.3 million. TNP used the dividend it received from TNMP to retire $84.3 million of debt outstanding under the Senior Credit Facility.

TNMP adopted SFAS No. 144, “Accounting for the Impairment of Long-Lived Assets,” during the fourth quarter of 2001. SFAS 144 requires entities to cease depreciation on long-lived assets held for sale and to measure such assets at the lower of the asset’s carrying amount or fair value less cost to sell.

Based on the sale, the fair value of TNP One, less cost to sell, was $117.5 million. TNMP believes that the difference between the fair value of TNP One, net of selling costs, and its book value of approximately $418.5 million at December 31, 2001, is recoverable from TNMP’s Texas transmission and distribution customers under the provisions of the 1999 Restructuring Legislation. Accordingly, TNMP recorded a regulatory asset for recoverable stranded cost of approximately $301.0 million. Under the provisions of the 1999 Restructuring Legislation, the amount and manner of stranded cost recovery is subject to review and approval by the PUCT as part of the 2004 true-up proceeding. Recovery of significantly less than the $301 million of estimated stranded costs could have a material impact on the financial position and cash flows of TNMP.

During the process of obtaining regulatory approval for the sale of TNP One, intervenors raised issues regarding the reasonableness of the sales price of TNP One and the effect of the sale on the rates paid by TNMP’s Texas transmission and distribution customers. The PUCT did not consider those issues at the time of the sale. Instead, the PUCT deferred consideration of those issues to the stranded cost true-up proceeding. The results of the final fuel reconciliation and the amount of the clawback, both of which were discussed in Note 2 to these consolidated financial statements, will also be considered in the stranded cost true-up proceeding.

The change in the book value of TNP One between January 1, 2002, and October 31, 2002, is not eligible for recovery under the stranded cost provisions of the 1999 Restructuring Legislation. Accordingly, TNMP recorded a pre-tax loss of $0.2 million ($0.1 million after tax) in December 2002 related to the ineligible costs, which consist primarily of capital additions subsequent to January 1, 2002.

The adjusted carrying value of TNP One was reclassified in the balance sheet of TNMP as Assets Held for Sale as of December 31, 2001. At that time, TNMP stopped depreciating TNP One. Depreciation on TNP One was $15.2 million and $15.4 million for the years ended December 31, 2001 and 2000, respectively.

~~Index to Financial Statements~~

In accordance with the provisions of the 1999 Restructuring Legislation, TGC became the unregulated entity performing the generation activities of TNMP as of January 1, 2002. During the first quarter of 2002, TGC sold the output of TNP One to First Choice and recorded revenue of $15.4 million related to the sales. The sales were priced at TGC’s cost of operating TNP One and, accordingly, TNP realized no net income from the sales. In the second and third quarters of 2002, pending the sale of TNP One, TGC sold the output of TNP One to third parties, including Sempra Energy Resources, the ultimate purchaser of TNP One. TGC recorded $35.0 million and $5.3 million of revenue and pre-tax income, respectively, related to the sales of TNP One output during the second and third quarters of 2002.

TNMP and its subsidiaries sponsor a defined benefit pension plan covering substantially all of its employees. Benefits are based on an employee’s years of service and compensation. TNMP’s funding policy is to contribute the minimum amount required by federal funding standards. TNMP provides an excess benefit plan for certain key personnel and retired employees whose benefits in the principal plan federal law restricts. TNMP also sponsors a health care plan that provides postretirement medical and death benefits to retirees who satisfied minimum age and service requirements during employment.

~~Index to Financial Statements~~

The Merger was accounted for under the purchase method of accounting. Acquired assets and assumed liabilities were recorded based on their estimated fair values. Accordingly, TNP recorded an asset for the pension plan assets in excess of the projected benefit obligations, and a liability for the postretirement projected benefit obligation in excess of the plan assets, thereby eliminating any previously existing unrecognized actuarial net gains or losses, prior service cost, and net transitional obligation. TNP also recorded a net regulatory liability associated with the pension plan and postretirement benefit plan that will be amortized in conjunction with TNMP’s amortization of its unrecognized gain or loss, unrecognized prior service cost, or unrecognized net transitional obligation, in order to reflect the amounts permitted for rate making purposes in operations.

The assumed health care cost trend rate used to measure the expected cost of benefits was 10 percent for 2002 and is assumed to trend downward slightly each year to 5 percent for 2007 and thereafter. TNMP’s exposure to cost increases in the postretirement benefit plan is minimized by a provision that limits TNMP’s share of costs under the plan. Costs of the plan in excess of the limit are borne wholly by the participants. TNMP reached the cost limit at the end of 2001. As a result, a one-percentage-point change in assumed health care cost trend rates would have no effect on either the 2002 net periodic expense or the year-end 2002 postretirement benefit obligation.

The projected benefit obligation of the excess benefit plan, which has an accumulated benefit obligation in excess of plan assets, was $6.3 million and $6.4 million at December 31, 2002 and 2001, respectively. The accumulated benefit obligation

~~Index to Financial Statements~~

of the excess benefit plan was $6.2 million and $5.3 million at December 31, 2002 and 2001, respectively. The excess benefit plan had no plan assets at December 31, 2002 and 2001, respectively.

TNMP and its subsidiaries have several incentive compensation plans. All employees participate in one or more of these plans. Incentive compensation is based on meeting key financial and operational performance goals such as cash flow from operations, customer satisfaction, and system reliability measures.

In connection with the Merger, TNMP entered into employment agreements with certain members of TNMP’s senior management. These agreements provide that the executive continues to hold his or her present position with TNMP and will receive a minimum level of compensation over the three years following the Merger. The employment agreements expire in April 2003. Expiration of the agreements will not change the status of the members of senior management that are covered by the employment agreements. Execution of new employment agreements is not a condition for the continued employment of the members of senior management that are parties to the employment agreements.

Operating expenses of TNMP for 2002, 2001, and 2000 included costs for the various plans and employment agreements of $2.7 million, $4.7 million, and $4.2 million, respectively.

TNMP and its subsidiaries have a 401(k) plan designed to enhance the other retirement plans available to its employees. Employees may invest their contributions in various mutual funds. TNMP’s contributions are invested in the same manner as the employee’s contributions. Operating expenses of TNMP for 2002, 2001, and 2000 included contribution costs of $0.6 million, $0.8 million and $0.8 million, respectively.

The amounts for total income taxes differ from the amounts computed by applying the appropriate federal income tax rate to earnings (loss) before income taxes for the following reasons:

~~Index to Financial Statements~~

The tax effects of temporary differences that gave rise to significant portions of net current and net noncurrent deferred income taxes as of December 31, 2002, and 2001, are presented below.

~~Index to Financial Statements~~

TNMP/First Choice Credit Facility. TNMP sold TNP One on October 31, 2002. TNMP used the net proceeds to retire $33.1 million of debt outstanding under the TNMP/First Choice Credit Facility and pay a dividend to TNP of $84.3 million. The debt reduction permanently reduced the commitment available under the TNMP/First Choice Credit Facility. As a result of the debt retirement, First Choice and TNMP may borrow up to $291.9 million under the TNMP/First Choice Credit Facility. TNMP may borrow subject to a guarantee by First Choice. First Choice may borrow funds, or have letters of credit issued, under the credit facility subject to a guarantee by TNMP. TNMP’s guarantee is limited to $75 million due to an order issued by the NMPRC in December 2001. Accordingly, First Choice’s borrowings and issuances of letters of credit are limited to $75 million.

As of December 31, 2002, TNMP had outstanding borrowings of $171.0 million against the TNMP/First Choice Credit Facility. TNMP had also guaranteed First Choice’s issuance of $36.5 million of letters of credit under the TNMP/First Choice Credit Facility. As a result, TNMP had the ability to borrow an additional $84.4 million under the TNMP/First Choice Credit Facility at December 31, 2002, subject to covenants in this facility, covenants in the Senior Credit Facility, and additional borrowings or issuances of letters of credit by First Choice.

As noted above, First Choice can borrow or issue letters of credit for up to $75 million under the TNMP/First Choice Credit Facility, subject to TNMP’s guarantee. At December 31, 2002, First Choice had issued letters of credit of $36.5 million, and TNMP had guaranteed First Choice’s performance under the power supply contract with Constellation for $25 million. As a result, First Choice had the ability to borrow or issue additional letters of credit in the amount of $13.5 million, subject to covenants in this facility, covenants in the Senior Credit Facility, and additional borrowings or issuances of letters of credit by TNMP. TNMP’s ability to guarantee First Choice’s $25 million performance under the Constellation contract is subject to TNMP maintaining an investment grade credit rating. Should TNMP lose its investment grade rating, First Choice would be required to issue additional letters of credit under the TNMP/First Choice Credit Facility.

The guarantees made by TNMP and First Choice require each to assume the obligations of the other in the event of default. As of December 31, 2002, TNMP had a maximum potential liability under its guarantees of First Choice borrowings, issuances of letters of credit and performance under the Constellation contract of $61.5 million. First Choice had a maximum potential liability under its guarantee of TNMP borrowings of $171 million. The guarantees are in force until the expiration of the TNMP/First Choice Credit Facility in October 2003.

As of December 31, 2002, the composite interest rate on the TNMP/First Choice Credit Facility was approximately 3.2 percent. For the years ended December 31, 2002, 2001 and 2000, the average interest rate on the TNMP/First Choice Credit Facility was approximately 3.0 percent, 5.7 percent and 8.1 percent, respectively.

The TNMP/First Choice Credit Facility expires in October 2003. TNMP and First Choice anticipate securing financing to replace the TNMP/First Choice Credit Facility prior to October 2003.

In March 2002, both the Senior Credit Facility and the TNMP/First Choice Credit Facility were amended to allow intercompany loans to be made between TNMP and First Choice. The availability of intercompany financing is an important source of liquidity for TNMP. As of December 31, 2002, TNMP had intercompany notes payable to First Choice of $14.6 million.

Factoring Arrangement. In February 2002, TNMP’s receivables factoring arrangement with an unaffiliated company, under which TNMP sold both billed and unbilled customer receivables on a nonrecourse basis, was terminated. The counterparty to this arrangement stopped factoring the receivables of non-affiliated businesses due to the significant changes resulting from the deregulation of the Texas electric market.

The termination of the factoring arrangement is the primary reason that TNMP’s consolidated accounts receivable has increased and cash flow from operations has decreased, compared with prior periods. As of December 31, 2002, TNMP’s consolidated accounts receivable were $33.7 million, net of allowance for uncollectible accounts of $0.2 million, compared with $8.0 million at December 31, 2001. The allowance for uncollectible accounts was zero at December 31, 2001, due to the presence of the factoring arrangement. TNMP’s consolidated cash flow from operations was $29.5 million for the year ended December 31, 2002, compared with $153.5 million for the year ended December 31, 2001.

~~Index to Financial Statements~~

As of December 31, 2002, scheduled maturities of long-term debt for the five years following 2002 are as follows:

The $171.0 million balance shown maturing in 2003 under the TNMP/First Choice Credit Facility is outstanding at TNMP. In addition to the cash maturities shown above, First Choice had $36.5 million of letters of credit outstanding under the TNMP/First Choice Credit Facility as of December 31, 2002. Those letters of credit expire during 2003.

The TNMP/First Choice Credit Facility restricts the payment of cash dividends by TNMP. TNMP may not declare or pay dividends if doing so would cause cumulative dividends declared or paid in the preceding twenty-four month period to exceed cumulative net income available for common stock in the same period. As of December 31, 2002, $47.0 million of unrestricted retained earnings were available for dividends.

Under an agreement between TNMP and its parent TNP, dated June 6, 1997 and an agreement between First Choice, TNMP’s affiliated retail electric provider, and TNMP, dated March 1, 2001, TNMP supplies various services, facilities, and supplies to TNP and First Choice. These services include accounting, information services, legal, and human resources, billed at TNMP’s cost. In return, TNP and First Choice compensate us for the use of the services, facilities and supplies. For the years ended December 31, 2002, 2001 and 2000, TNMP billed TNP $2.1 million, $1.4 million and $9.3 million, respectively. For the years ended December 31, 2002 and 2001, TNMP billed First Choice $11.4 million and $1.6 million, respectively. At December 31, 2002, 2001 and 2000, TNP owed TNMP $1.1 million, $0.4 million, and $0.6 million, respectively, for the services, facilities, and supplies. At December 31, 2002 and 2001, First Choice owed TNMP $3.0 million and $2.0 million, respectively, for the services, facilities, and supplies.

Additionally, TNMP recorded affiliated revenue for the year ended December 31, 2002, for transmission and distribution charges billed to First Choice in the amount of $107.7 million with a balance owed to TNMP at December 31, 2002 of $16.6 million.

In March 2002, the TNMP/First Choice Credit Facility was amended to allow loans to be made between TNMP and First Choice. As of December 31, 2002, TNMP had notes payable to First Choice of $14.6 million.

During the first quarter of 2002, TNMP sold the output of TNP One to First Choice at cost. TNMP billed First Choice $15.4 million for the power.

~~Index to Financial Statements~~

Texas.In January 2002, TNMP’s power contracts for Texas operations were assigned to First Choice, and Constellation began managing those contracts on behalf of First Choice. Constellation is the primary supplier of power for First Choice’s price-to-beat customers. As First Choice gains competitive customers, it procures power for those competitive customers from a number of suppliers.

New Mexico. TNMP’s power requirements in New Mexico are supplied by PNM under a long-term wholesale power contract that expires in December 2006. In addition to providing power supply, PNM acts as TNMP’s agent to procure, schedule and dispatch wholesale power on TNMP’s behalf throughout the term of the contract.

Take or Pay Obligations. At December 31, 2002, TNMP and First Choice had various outstanding commitments for take or pay provisions in its energy supply agreements. Detailed below are the fixed and determinable portion of the obligations (amounts in millions):

Transmission Cost of Service.In June 2001 the Supreme Court of Texas overturned the methodology adopted by the PUCT to determine how much companies pay and charge for transmission services for the period January 1, 1997, through August 31, 1999. The PUCT had ordered a uniform methodology for the entire state and the Supreme Court stated that the costs needed to be determined on an individual company basis. There are currently two court cases and a regulatory proceeding pending that attempt to address the issues. TNMP is a defendant in both of the court cases, and has intervened in the regulatory proceeding. TNMP benefited from the PUCT’s original methodology. During 2002, parties to the proceedings attempted to negotiate a settlement of the contested issues, but an agreement has not yet been reached. TNMP cannot predict if the settlement discussions will ultimately result in a resolution of the contested issues, or how any such resolution will affect the financial condition, results of operations, or cash flows of TNMP.

In October 2001, the Pennsylvania Insurance Department announced that it would liquidate Reliance Insurance Company (Reliance), TNMP’s primary general liability insurance carrier from 1997 through 1999. TNMP estimates that it has claims with Reliance ranging from $0 to $0.5 million. Management does not believe that the liquidation of Reliance will have a material adverse effect on its consolidated financial condition or results of operations.

TNP and TNMP are involved in various claims and other legal proceedings arising in the ordinary course of business. In the opinion of management, the ultimate dispositions of these matters will not have a material adverse effect on TNMP’s and TNP’s consolidated financial condition or results of operations. However, if all of the various claimants were to prevail, TNP and TNMP could be exposed to liabilities of up to $3.9 million.

~~Index to Financial Statements~~

The following selected quarterly consolidated financial data for TNMP is unaudited, and, in the opinion of TNMP’s management, is a fair summary of the results of operations for such periods:

Generally, the variations between quarters reflect the seasonal fluctuations of the business of TNMP.

~~Index to Financial Statements~~

The accompanying notes are an integral part of these consolidated financial statements.

~~Index to Financial Statements~~

The accompanying notes are an integral part of these consolidated financial statements.

~~Index to Financial Statements~~

The accompanying notes are an integral part of these consolidated financial statements.

~~Index to Financial Statements~~

The accompanying notes are an integral part of these consolidated financial statements.

~~Index to Financial Statements~~

The consolidated interim financial statements of TNMP and subsidiaries are unaudited and contain all adjustments (consisting primarily of normal recurring accruals) necessary for a fair statement of the results for the interim periods presented. Results for interim periods are not necessarily indicative of results to be expected for a full year or for previously reported periods due in part to seasonal revenue fluctuations. It is suggested that these consolidated interim financial statements be read in conjunction with the audited consolidated financial statements and notes thereto included in TNP’s and TNMP’s 2002Combined Annual Report on Form 10-K.

Prior period statements have been reclassified in order to be consistent with current period presentation. The reclassification had no effect on net income or common shareholder’s equity.

Retail Competition. As reported in the 2002 Combined Annual Report on Form 10-K, the Texas electricity market has been open to retail competition since January 1, 2002. In accordance with The 1999 Restructuring Legislation, the legislation that established retail competition, TNMP provides transmission and distribution services at regulated rates to customers within its service area. While TNMP provides transmission and distribution services to individual consumers, its revenues are collected from the various retail electric providers that provide electric service within TNMP’s service area.

Clawback. The 1999 Restructuring Legislation includes a provision, commonly known as the “clawback,” that would require First Choice to credit TNMP the difference between the price-to-beat and the market price of electricity during the years 2002 and 2003. The PUCT will determine the amount of the clawback credit in the true-up proceeding that will occur in 2004. The maximum credit to TNMP is limited to $150 multiplied by the difference between the number of First Choice price-to-beat customers and the number of First Choice competitively acquired residential and small commercial customers as of January 1, 2004. Based on current projections, First Choice estimates that its clawback liability will be $16.7 million. Accordingly, First Choice increased its pre-tax reserve of $12.7 million recorded at December 31, 2002, by $4.0 million for the nine months ended September 30, 2003, which includes a $3.6 million increase in the third quarter of 2003.

Final Fuel Reconciliation. Prior to the beginning of retail competition, TNMP recovered fuel and the energy-related portion of purchased power costs from customers through the fuel adjustment clause authorized by the PUCT. The demand-related portion of purchased power was recovered through base rates and, unlike the fuel and energy-related portion, was not subject to adjustment or future reconciliation. As of September 30, 2003, TNMP had an over-recovered balance of fuel and energy-related purchased power costs of $24.3 million. On April 1, 2003, TNMP filed an application with the PUCT for the final reconciliation of its fuel and energy-related purchased power costs. This proceeding will reconcile fuel and energy-related purchased power costs incurred between January 1, 2000, and December 31, 2001, in accordance with the provisions of Senate Bill 7. The balance of fuel and energy-related purchased power costs resulting from the final fuel reconciliation will be included in the true-up proceeding for stranded costs that will occur in 2004. Subject to the results of the final fuel reconciliation, any over-recovered balance may reduce the amount of stranded costs TNMP would be entitled to recover from its transmission and distribution customers.

On November 19, 2003, the administrative law judge assigned to this proceeding by the State Office of Administrative Hearings issued a Proposal for Decision in the fuel reconciliation. The Proposal for Decision recommends that $16.4 million of TNMP’s fuel and energy-related purchased power costs incurred between January 1, 2000, and December 31, 2001, be disallowed. TNMP will contest the Proposal for Decision. TNMP expects the PUCT to render its final decision in the fuel reconciliation in mid-December 2003 and TNMP cannot predict what the PUCT’s final decision in the fuel reconciliation will be.

2001 Excess Earnings. As reported in the 2002 Combined Annual Report on Form 10-K, TNMP filed a petition in November 2002 asking the PUCT to allow TNMP to establish a regulatory asset of $3.1 million, the amount of its 2001 Annual Report earnings deficiency that is attributable to System Benefit Fund payments. In August 2003, the PUCT approved TNMP’s petition and granted it authority to record the regulatory asset and accrue a return retroactive to December 31, 2001. The order requires TNMP to seek recovery of the regulatory asset in a base rate proceeding instituted on or before July 1, 2005, or forfeit the right to seek recovery of the regulatory asset.

~~Index to Financial Statements~~

As a result of the PUCT order, TNMP’s pre-tax net income for the three and nine months ended September 30, 2003, increased $3.6 million ($2.3 million after tax).

Merger Commitments. As conditions for approval of the Merger, TNMP made a number of commitments to both the PUCT and New Mexico Public Regulation Commission (NMPRC). The commitments cover a wide range of financial, operational, electric reliability, and other standards with which TNMP agreed to comply. TNMP made 55 commitments in New Mexico and Texas, of which 47 are currently in effect. TNMP monitors compliance on a monthly basis and could be subject to financial penalties for non-compliance with certain commitments. During the years ended December 31, 2002 and 2001, TNMP was not in compliance with certain commitments regarding electric reliability standards in Texas, and as a result paid $0.2 million in penalties during the second quarter of 2003.

2004 True-Up Proceeding. The PUCT established the schedule for the stranded cost true-up proceeding that will occur in 2004. TNMP is required to file its stranded cost true up under the provisions of The 1999 Restructuring Legislation between January 12 and January 22, 2004.

Cities Rate Review. In October 2003, the City of Dickinson passed an ordinance requiring TNMP to file certain financial information with the city so that the city may determine whether TNMP’s transmission and distribution rates are reasonable. TNMP cannot predict what action the city may take, or what effects any such action may have on its financial position, cash flows, or results of operation at this time.

Affiliated Guarantee. In October 2003, the NMPRC granted TNMP’s request for the authority to extend a portion of the guarantees that TNMP provides for certain power supply obligations of First Choice. The NMPRC originally granted TNMP authority to guarantee up to $75 million of First Choice obligations in December 2001. That authority was set to expire at the end of October 2003. TNMP agreed to a number of conditions in return for the authority to guarantee First Choice’s power supply obligations, including the following:

TNMP withdrew the request it made in June 2003 for authority to place its New Mexico operations in a separate wholly owned subsidiary of TNMP.

TNMP’s authority to guarantee First Choice’s power supply obligations is limited to $50 million. That amount will consist of TNMP’s $25 million guarantee of First Choice’s performance under the Constellation power supply agreement and no more than $25 million in guarantees of First Choice’s performance under additional power supply agreements.

TNMP’s authority to guarantee First Choice’s power supply obligations ends on December 31, 2004, or on the date that First Choice executes power supply agreements that no longer require TNMP’s guarantee, whichever occurs first.

TNMP will not seek to recover any liability for performance under the guarantees from its New Mexico customers.

During the term of the guarantee, TNMP will not seek to recover a cost of capital from its New Mexico customers other than the cost of capital that would be available to TNMP if it had an investment grade credit rating, regardless of TNMP’s actual credit rating.

Reorganization of New Mexico Operations. As noted above, TNMP withdrew its motion for authority to place its New Mexico operations in a separate wholly owned subsidiary of TNMP in October 2003 when the NMPRC granted TNMP’s request for authority to guarantee certain power supply obligations of First Choice.

Restructuring. During its 2003 regular session, the New Mexico Legislature repealed the New Mexico Restructuring Act, which had established a framework for retail competition in the New Mexico electricity market. Retail competition was scheduled to begin no earlier than 2007 prior to the repeal. Accordingly, TNMP’s New Mexico operations will continue to be subject to cost-based regulation and the repeal had no effect on the financial position, results of operations or cash flows of TNMP, as retail competition had not been implemented yet.

TNP and TNMP adopted SFAS No. 143, “Accounting for Asset Retirement Obligations,” on January 1, 2003. The adoption had no impact on the financial position, results of operations, or cash flows of TNP and TNMP. As a result of the adoption of SFAS 143, TNP and TNMP identified costs recorded in accumulated depreciation related to inclusion of removal costs of utility plant in TNMP’s rates by the PUCT and NMPRC. Such costs do not arise from legal obligations. Rather, they represent long-standing regulatory policy to include charges for removal costs of utility plant in accumulated depreciation. As of September 30, 2003, $37.9 million of estimated utility plant removal costs were included in accumulated depreciation.

~~Index to Financial Statements~~

TNMP adopted SFAS No. 149, “Amendments of Statement 133 on Derivative Instruments and Hedging Activities” (SFAS 149), on June 30, 2003. The adoption had no impact on the financial position, results of operations, or cash flows of TNMP. SFAS 149 amends SFAS 133 for decisions made by the Derivatives Implementation Group that required amendments to SFAS 133, in connection with other Financial Accounting Standards Board projects regarding financial instruments, and for implementation issues regarding the application of the definition of a derivative.

TNMP may enter into derivative instruments, including options and swaps, to manage risks related to changes in interest rates and commodity prices. At the inception of any such transactions, TNMP documents relationships between the hedging instruments and the items being hedged. The documentation includes the strategy that supports executing the specific transaction.

TNMP Interest Rate Hedges. In October 2002, TNMP executed two $75 million interest rate swap transactions designed to manage interest rate risk associated with the TNMP/First Choice Credit Facility. As discussed in Note 5, TNMP issued $250 million of Senior Notes in June 2003. A portion of the proceeds from that borrowing was used to repay amounts outstanding under the TNMP/First Choice Credit Facility. As a result, TNMP terminated the swaps in June 2003 at a cost of $3.1 million, which was recorded in interest expense.

In May 2003, TNMP executed a $250 million Treasury rate lock transaction designed to manage interest rate risk associated with the issuance of its $250 million of Senior Notes discussed in Note 5. The rate lock effectively fixed the five-year Treasury yield upon which the yield of the Senior Notes was based at approximately 2.6 percent. TNMP paid $4.2 million upon the issuance of the Senior Notes in June 2003 to settle the rate lock. The cost of the rate lock was recorded in accumulated other comprehensive income and will be amortized to interest expense over the life of the Senior Notes.

The interest rate swaps and the Treasury rate lock were designated as cash flow hedges. The instruments were highly effective in offsetting future cash flow volatility caused by changes in interest rates. For the three and nine months ended September 30, 2003, TNMP recorded unrealized gains (losses), net of reclassification adjustments, associated with its interest rate swaps and Treasury rate lock in other comprehensive income as shown in the following table.

TNMP displays cash flows from interest rate hedging transactions in the cash flow statement as cash flow from operations, in accordance with the provisions of SFAS No. 104, “Statement of Cash Flows-Net Reporting of Certain Cash Receipts and Cash Payments and Classification of Cash Flows from Hedging Transactions.”

~~Index to Financial Statements~~

TNMP Senior Notes. On June 10, 2003, TNMP completed the sale of $250 million of 6.125% existing notes due 2008. The proceeds from this sale were used to repay all of our outstanding borrowings under the TNMP/First Choice Credit Facility, which were $207 million as of June 10, 2003. At the same time, we reduced the commitment available for borrowing under that facility from $291.9 million to $90 million. As a result of the sale, TNMP has adequate cash to meet its working capital needs without the need for additional bank financing through at least the end of 2005.

TNMP/First Choice Credit Facility. Following the sale of the existing notes, First Choice was able to borrow from the TNMP/First Choice Credit Facility until its expiration in October 2003. First Choice could borrow funds, or have letters of credit issued, under the credit facility subject to a guarantee by TNMP. TNMP’s guarantee was limited to $75 million due to an order issued by the NMPRC in December 2001. At September 30, 2003, First Choice had issued letters of credit of $28.7 million under the TNMP/First Choice Credit Facility. In addition, TNMP had guaranteed First Choice’s performance under the power supply contract with Constellation for $25 million. As a result, First Choice had additional capacity to borrow or issue letters of credit under the TNMP/First Choice Credit Facility of $21.3 million as of September 30, 2003.

The guarantees made by TNMP and First Choice required each to assume the obligations of the other in the event of default. As of September 30, 2003, TNMP had a maximum potential liability under its guarantees of First Choice borrowings, issuances of letters of credit and performance under the Constellation contract of $53.7 million. The guarantees were in force until the expiration of the TNMP/First Choice Credit Facility in October 2003.

As of September 30, 2003, First Choice had no guarantees of TNMP borrowings in force as a result of TNMP’s repayment of its outstanding borrowings under the TNMP/First Choice Credit Facility, as discussed above.

The TNMP/First Choice Credit Facility expired in October 2003. Also in October 2003, the NMPRC granted TNMP the authority to guarantee up to $50 million of First Choice power supply obligations as discussed in Note 2 to these consolidated interim financial statements.

As noted above, the issuance of the existing notes resulted in TNMP having adequate cash to meet its working capital needs. On October 28, 2003, First Choice executed a Letter of Intent and Security Agreement with Constellation under which Constellation will supply First Choice the majority of its remaining power requirements through the end of 2006. As part of the agreement, First Choice will grant a security interest in its accounts receivable to Constellation, providing First Choice with sufficient credit for its Texas operations. This agreement eliminates the need for a new credit facility First Choice had been negotiating, or the renewal of the existing revolving credit facility.

The new agreement with Constellation requires TNMP to continue to guarantee First Choice’s performance under the agreement for $25 million. However, the $28.7 million of letters of credit that First Choice had outstanding at September 30, 2003, were released as a result of the new Constellation agreement. In addition, Constellation has agreed to waive its right to require First Choice to post collateral to cover both settlement exposure and mark-to-market exposure. Accordingly, TNMP had a maximum potential liability under its guarantee of First Choice performance under the new Constellation agreement of $25 million as of October 27, 2003, the date upon which the new Constellation agreement was executed. The guarantee will be in force until the earlier of December 31, 2004 or the date upon which Constellation releases TNMP from its obligation to guarantee First Choice’s performance under the new Constellation agreement.

Under an agreement between TNMP and its parent TNP, dated June 6, 1997 and an agreement between First Choice, TNMP’s affiliated retail electric provider, and TNMP, dated March 1, 2001, TNMP supplies various services, facilities, and supplies to TNP and First Choice. These services include accounting, information services, legal, and human resources, billed at TNMP’s cost. In return, TNP and First Choice compensate TNMP for the use of the services, facilities and supplies. For the three and nine months ended September 30, 2003, TNMP billed TNP $0.3 million, and $1.4 million, respectively, for those services. For the three and nine months ended September 30, 2003, TNMP billed First Choice $3.4 million and $9.9 million, respectively. At September 30, 2003, TNP owed TNMP $0.6 million for the services, facilities, and supplies. At September 30, 2003, First Choice owed TNMP $1.8 million for the services, facilities, and supplies.

Additionally, TNMP recorded affiliated revenue for the three and nine months ended September 30, 2003, for transmission and distribution charges billed to First Choice of $29.9 million and $83.8 million, respectively. First Choice owed TNMP $13.4 million for transmission and distribution charges at September 30, 2003.

~~Index to Financial Statements~~

In March 2002, the TNMP/First Choice Credit Facility was amended to allow loans to be made between TNMP and First Choice. As of June 30, 2003, all loans between TNMP and First Choice were retired. Due to the sale of the existing notes discussed in Note 5 to the consolidated interim financial statements, TNMP does not expect to utilize loans form First Choice in the foreseeable future.

Amendment to Power Supply and Service Agreement. On March 31, 2003, First Choice and Constellation amended the power supply and service agreement under which First Choice purchases power to serve its price-to-beat load. The amendment modified the conditions under which TNMP is able to guarantee First Choice’s performance under the power supply and service agreement. Previously, TNMP’s ability to guarantee up to $25 million of First Choice’s performance under the power supply and service agreement was subject to TNMP maintaining credit ratings of at least BBB- by S&P and at least Ba1 by Moody’s. As amended, TNMP can guarantee First Choice’s performance for up to $25 million if its credit rating is at least BB+ by S&P or at least Ba1 by Moody’s.

TNP and TNMP are involved in various claims and other legal proceedings arising in the ordinary course of business. In the opinion of management, the dispositions of these matters will not have a material adverse effect on TNP’s and TNMP’s consolidated financial condition or results of operations.

~~Index to Financial Statements~~

Pursuant to the requirements of the Securities Act, the registrant has duly caused this Amendment No. 23 to be signed on its behalf by the undersigned, thereunto duly authorized, in the city of Fort Worth, State of Texas on ~~November 26,~~December 8, 2003.

TEXAS-NEW MEXICO POWER COMPANY

By:		/s/ Jack V. Chambers
Jack V. Chambers, Chairman, President and Chief Executive Officer

By:		/s/ Scott Forbes
Scott Forbes, Senior Vice President & Chief Financial Officer

By:		/s/ Joseph Hegwood
Joseph Hegwood, Vice President & Controller

Pursuant to the requirements of the Securities Act of 1933, this Amendment No. 23 has been signed by the following persons or their attorney in fact in the capacities and on the dates indicated.

~~Index to Financial Statements~~

Exhibits filed with this registration statement are denoted by “*.” Agreements with management are denoted by “+”. Exhibits incorporated by reference to prior filings are noted in parentheses.

		Page
PROSPECTUS SUMMARY		1
RISK FACTORS		11
RATIO OF EARNINGS TO FIXED CHARGES		19
USE OF PROCEEDS		19
CAPITALIZATION		20
SELECTED HISTORICAL FINANCIAL AND OPERATING DATA		21
MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS		24
BUSINESS		39
LEGAL PROCEEDINGS		45
MANAGEMENT		47
EXECUTIVE COMPENSATION		50
DESCRIPTION OF THE SENIOR NOTES		56
THE EXCHANGE OFFER		68
MATERIAL U.S. FEDERAL INCOME TAX CONSIDERATIONS		75
PLAN OF DISTRIBUTION		78
LEGAL MATTERS		79
EXPERTS		79
FORWARD-LOOKING STATEMENTS		79
WHERE YOU CAN FIND MORE INFORMATION		80
INDEX TO FINANCIAL STATEMENTS		F-1
INDEX TO UNAUDITED FINANCIAL STATEMENTS		F-1
INDEPENDENT AUDITORS’ REPORT		F-2
Notes to Consolidated Financial Statements		F-8
Selected Quarterly Consolidated Financial Data		F-21
Notes to Consolidated Interim Financial Statements		F-26

	Year Ended December 31,
	2002	2001	2000	1999	1998
Ratio of earnings to fixed charges (1)	3.5x	3.8x	2.6x	2.4x	1.9x
Pro Forma Ratio of earnings to fixed charges (2)	2.5x

	For the Twelve Months Ended September 30, 2003
Ratio of earnings to fixed charges (1)	3.1x
Pro Forma Ratio of earnings to fixed charges (2)	2.7x

	As of September 30, 2003
	Actual			Adjustments		As Adjusted
	(In thousands)
Cash and cash equivalents	$	65,218		$	—	$	65,218

Common shareholder’s equity	$	248,537			—	$	248,537

Long-term debt (including current maturities)
6.25% senior notes		175,000			—		175,000
6.125% senior notes		250,000			—		250,000
Unamortized discount		(1,448	)		—		(1,448	)

Total debt		423,552			—		423,552

Total capitalization	$	672,089		$	—	$	672,089

	Nine Months Ended September 30,						Year Ended December 31,
	2003			2002			2002			2001			2000			1999			1998
	(In thousands)
Income statement data
Operating revenues	$	199,079		$	240,513		$	303,907		$	651,532		$	644,035		$	576,093		$	585,892

Operating expenses
Purchased power and fuel		50,843			83,093			100,679			369,857			348,461			279,587			315,949
Other operating and maintenance		47,544			57,233			75,240			98,472			97,466			99,390			91,663
Depreciation of utility plant		21,374			20,725			27,567			42,350			41,353			39,295			38,054
Charge (credit) for recovery of stranded plant		—			(733	)		(733	)		1,377			18,306			23,376			—
Taxes other than income taxes		16,088			19,749			24,507			34,659			34,615			33,296			36,298

Total operating expenses		135,849			180,067			227,260			546,715			540,201			474,944			481,964

Operating income		63,230			60,446			76,647			104,817			103,834			101,149			103,928
Interest on long-term debt		18,670			13,883			18,300			24,001			35,231			37,919			48,342
Other interest and amortization of debt-related costs		1,977			2,686			3,514			3,172			5,291			5,205			5,385
Other income and deductions, net		(1,631	)		(315	)		(464	)		(1,116	)		(1,626	)		(1,940	)		(1,035	)

Income before income taxes		44,214			44,192			55,297			78,760			64,938			59,965			51,236
Income taxes		16,031			14,930			19,166			26,626			22,981			20,522			16,915

Income before cumulative effect of change in accounting		28,183			29,262			36,131			52,134			41,957			39,443			34,321
Cumulative effect of change in accounting for major maintenance costs, net of taxes (Note 3)		—			—			—			(1,170	)		—			—			—

Net income		28,183			29,262			36,131			50,964			41,957			39,443			34,321
Dividends on preferred stock and other		—			—			—			—			38			(19	)		150

Income applicable to common stock	$	28,183		$	29,262		$	36,131		$	50,964		$	41,919		$	39,462		$	34,171

Balance sheet data
Cash and cash equivalents	$	65,218		$	657		$	284		$	5,634		$	2,613		$	4,002		$	7,977
Net utility plant		511,316			496,448			503,910			493,649			911,988			907,954			922,831
Total assets		937,402			968,215			862,805			940,799			998,497			984,395			973,566
Total debt		423,552			410,374			345,495			342,411			426,327			440,244			450,000
Redeemable cumulative preferred stock		—			—			—			—			—			1,664			3,060
Common shareholder's equity		248,537			329,161			250,994			337,411			322,977			312,558			302,096

	Nine Months Ended September 30,				Year Ended December 31,
	2003		2002(1)		2002(1)		2001			2000		1999		1998
Operating revenues (in thousands):
Residential	$	71,973	$	81,998	$	102,464	$	264,704		$	231,953	$	216,374	$	225,870
Commercial		69,659		72,022		94,052		210,378			176,635		163,248		164,800
Industrial		33,254		31,402		42,089		173,885			172,908		147,110		150,883
Sales for resale (2)		—		50,354		53,806		12,499			12,350		3,803		11,448
Other		24,193		4,737		11,496		(9,934	)		50,189		45,558		32,891

Total	$	199,079	$	240,513	$	303,907	$	651,532		$	644,035	$	576,093	$	585,892

Sales (MWh):
Residential		2,121,158		2,047,450		2,622,978		2,555,472			2,582,081		2,420,512		2,439,478
Commercial		1,640,268		1,607,286		2,095,666		2,089,978			2,069,046		1,921,614		1,883,422
Industrial		1,691,028		1,513,426		1,958,920		4,166,178			4,610,059		4,799,146		4,981,773
Sales for resale (2)		—		1,906,972		1,978,194		291,958			281,017		121,077		428,884
Other		85,884		83,659		110,592		99,884			101,563		106,814		109,867

Total		5,538,338		7,158,793		8,766,350		9,203,470			9,643,766		9,369,163		9,843,424

Number of customers (at period end):
Residential		214,148		209,995		210,936		205,712			202,759		199,617		197,155
Commercial		35,414		35,027		34,979		33,654			34,345		33,127		30,884
Industrial		122		140		114		117			116		116		138
Sales for resale (2)		—		1		—		—			16		8		17
Other		811		835		835		802			788		799		226

Total		250,495		245,998		246,864		240,285			238,024		233,667		228,420

Revenue statistics:
Average use per residential customer (kWh)		9,969		9,823		12,554		12,451			12,805		12,130		12,491
Average revenue per residential customer (dollars)		338		393		490		1,290			1,150		1,084		1,157
Average revenue per kWh sold per residential customer (cents)		3.39		4.00		3.91		10.36			8.98		8.94		9.26
Average revenue per kWh sold total sales (cents)		3.59		3.36		3.47		7.08			6.68		6.15		5.95
Net generation and purchases (MWh):
Generated		—		1,902,867		2,010,606		2,349,380			2,215,236		1,912,673		2,062,958
Purchased		743,030		961,988		1,106,924		7,145,034			7,686,302		7,716,856		8,256,857

Total		743,030		2,864,855		3,117,530		9,494,414			9,901,538		9,629,529		10,319,815

Average cost per kWh purchased (cents)		6.84		5.16		5.85		4.58			4.01		3.18		3.39

Employees (period-end)		569		631		578		748			830		823		827

	Earnings Increase (Decrease)
	Three Months Ended September 30, 2003 v. 2002			Nine Months Ended September 30, 2003 v. 2002
Changes in gross profit	$	(7.6	)	$	(10.0	)
Other operating and maintenance		7.1			10.5
Taxes other than income taxes		1.0			3.7
Interest charges		(1.3	)		(4.1	)
All other (including income tax effects on the items above)		—			(1.2	)

TNMP consolidated earnings decrease	$	(0.8	)	$	(1.1	)

	Three Months Ended September 30,							Nine Months Ended September 30,
	2003		2002		Increase (Decrease)			2003		2002		Increase (Decrease)
Operating revenues	$	69,953	$	86,367	$	(16,414	)	$	199,079	$	240,513	$	(41,434	)

Purchased power and fuel		17,542		26,588		(9,046	)		50,843		83,093		(32,250	)
Transmission expense		5,257		5,045		212			15,616		14,755		861

Gross profit	$	47,154	$	54,734	$	(7,580	)	$	132,620	$	142,665	$	(10,045	)

	Three Months Ended September 30, 2003 v. 2002			Nine Months Ended September 30, 2003 v. 2002
January 2002 unbundled rates	$	—		$	(4,606	)
Sales of TNP One output – 2002, net		(6,700	)		(16,925	)
Electric service revenues		219			3,614
Customer growth		640			2,471
Weather related		(2,207	)		2,300
Price/sales mix and other		468			3,101

Gross profit decrease	$	(7,580	)	$	(10,045	)

	Earnings Increase (Decrease)
	2002 v. 2001			2001 v. 2000
Changes in gross profit	$	(83.6	)	$	(15.4	)
Other operating and maintenance expenses		28.4			0.5
Depreciation of utility plant		14.8			(1.0	)
Charge for recovery of stranded plant		2.1			16.9
Taxes other than income taxes		10.2			—
Interest charges		5.4			13.3
All other (including income tax effects on the items above)		6.7			(4.1	)
Cumulative effect of change in accounting for major maintenance costs (net of tax)		1.2			(1.2	)

TNMP consolidated earnings increase (decrease)	$	(14.8	)	$	9.0

									Increase (Decrease)
	2002		2001			2000			2002 v. 2001			2001 v. 2000
Operating revenues, excluding transmission	$	287,576	$	630,533		$	624,214		$	(342,957	)	$	6,319
Direct costs
Purchased power and fuel		100,679		369,857			348,461			(269,178	)		21,396
Transmission expense, net of revenue		3,360		(6,434	)		(6,745	)		9,794			311

Gross profit	$	183,537	$	267,110		$	282,498		$	(83,573	)	$	(15,388	)

	2002	2001	Variance		%
Residential	2,623	2,555	68		2.7
Commercial	2,096	2,090	6		0.3
Industrial	1,959	4,166	(2,207	)	(53.0	)
Sales for resale	1,978	292	1,686		577.4
Other	111	100	11		11.0

Total GWH Sales	8,767	9,203	(436	)	(4.7	)

	2003		2004		2005		2006		2007
TNMP Capital expenditures		44.6		39.0		38.5		38.5		38.5

Total capital requirements	$	44.6	$	39.0	$	38.5	$	38.5	$	38.5

			Payments due in
	Total		Less than 1 Year		1-3 Years		3-5 Years		More than 5 years
Long-term debt (See Note 8)	$	425.0	$	—	$	—	$	250.0	$	175.0
Obligations under purchased power agreements
(See Note 11)		53.8		13.6		26.5		13.7		—

Total	$	478.8	$	13.6	$	26.5	$	263.7	$	175.0

Name	Age	Position with TNMP
Jack V. Chambers	54	Chairman, President, & Chief Executive Officer
Scott Forbes	45	Senior Vice President – Chief Financial Officer
W. Douglas Hobbs	59	Senior Vice President & Chief Operations Officer
Melissa D. Davis	46	Vice President – Human Resources
Michael D. Blanchard	53	Vice President & General Counsel
Joseph B. Hegwood	47	Vice President & Controller
Adam Carte	34	Vice President & Treasurer
Georgia (Cookie) Chambers	45	Chief Information Officer
Paul W. Talbot	47	Secretary
B. Jan Adkins	59	Assistant Secretary

Title of Class	Name of Beneficial Owner	Nature of Beneficial Ownership	Percent of Class
Common Stock	SW Acquisition (1)	1000 shares	100.0%
Common Stock	William J. Catacosinos (2)	1000 shares	100.0%
	Jack V. Chambers(3)		0.0%
	Leeam Lowin (3)		0.0%
	James T. Flynn(3)		0.0%
	Preston M. Geren, III(3)		0.0%
	Manjit S. Cheema(3)		0.0%
	W. Douglas Hobbs(3)		0.0%
	Michael D. Blanchard(3)		0.0%
	Melissa D. Davis(3)		0.0%
	All directors and officers as a group (2)		100.0%

	401(k) Plan	Life Insurance Premiums
Mr. Chambers	9,663	914
Mr. Cheema	8,772	2,286
Mr. Hobbs	11,000	1,532
Mr. Dillon	9,078	841
Mr. Blanchard	8,902	795
Ms. Davis	8,902	823
Mr. Bridges	8,902	—

Name	Total Annuity		Pension Plan Annuity		Excess Benefit Plan Annuity
Chambers, Jack V.	$	114,000	$	49,000	$	65,000
Hobbs, William D.		31,000		21,000		10,000
Cheema, Manjit S.		98,000		37,000		61,000
Blanchard, Michael D.		57,000		40,000		17,000
Davis, Melissa D.		75,000		48,000		27,000

	Years of Service
Remuneration (1)	15		20		25		30		35		40
$125,000	$	29,328	$	39,104	$	48,880	$	58,656	$	68,432	$	76,557
150,000		35,703		47,604		59,505		71,406		83,307		93,057
175,000		42,078		56,104		70,130		84,156		98,182		109,557
200,000		48,453		64,604		80,755		96,906		113,057		126,057
250,000		61,203		81,604		102,005		122,406		142 807		159,057
300,000		73,953		98,604		123,255		147,906		172,557		192,057
350,000		86,703		115,604		144,505		173,406		202,307		225,057
400,000		99,453		132,604		165,755		198,906		232,057		258,057
450,000		112,203		149,604		187,005		224,406		261 807		291,057
500,000		124,953		166,604		208,255		249,906		291,557		324,057

If redeemed during the 6 months beginning		Applicable Redemption Price*
May 1, 2005		102.50%
November 1, 2005		102.00
May 1, 2006		101.50
November 1, 2006		101.00
May 1, 2007		100.50
November 1, 2007		100.00

INDEPENDENT AUDITORS’ REPORT		F-2
Consolidated Statements of Income, Three Years Ended December 31, 2002		F-3
Consolidated Statements of Cash Flows, Three Years Ended December 31, 2002		F-4
Consolidated Balance Sheets, December 31, 2002 and 2001		F-5
Consolidated Statements of Capitalization, December 31, 2002 and 2001		F-6
Consolidated Statements of Common Shareholder’s Equity, Three Years Ended December 31, 2002		F-7
Notes to Consolidated Financial Statements		F-8
Selected Quarterly Consolidated Financial Data		F-21

INDEX TO UNAUDITED FINANCIAL STATEMENTS

Consolidated Statements of Income, Three and Nine Month Periods Ended September 30, 2003 and 2002		F-22
Consolidated Statements of Comprehensive Income, Three and Nine Month Periods Ended September 30, 2003 and 2002		F-23
Consolidated Statements of Cash Flows, Nine Month Periods Ended September 30, 2003 and 2002		F-24
Consolidated Balance Sheets, September 30, 2003 and December 31, 2002		F-25
Notes to Consolidated Interim Financial Statements		F-26

	2002			2001
	*(In thousands)*
*ASSETS*
CURRENT ASSETS:
Cash and cash equivalents	$	284		$	5,634
Accounts receivable, net
Affiliated		16,633			—
Non-affiliated		17,045			8,024
Materials and supplies, at lower of cost or market		992			1,109
Deferred purchased power and fuel costs		1,320			1,852
Accumulated deferred income taxes		70			1,570
Assets held for sale		—			103,500
Other current assets		612			520

Total current assets		36,956			122,209

UTILITY PLANT:
Electric plant		770,960			757,230
Construction work in progress		11,707			3,147

Total		782,667			760,377
Less accumulated depreciation		278,757			266,728

Net utility plant		503,910			493,649

LONG-TERM AND OTHER ASSETS:
Other property and investments, at cost		343			334
Recoverable stranded costs		298,748			311,944
Regulatory tax assets		913			130
Deferred charges		21,935			12,533

Total long-term and other assets		321,939			324,941

	$	862,805		$	940,799

*LIABILITIES AND SHAREHOLDER’S EQUITY*
CURRENT LIABILITIES:
Current maturities of long-term debt	$	171,000		$	—
Notes payable to affiliate		14,557			—
Accounts payable		9,543			31,952
Accrued interest		5,345			5,526
Accrued taxes		9,923			22,213
Customers’ deposits		1,092			5,776
Other current liabilities		9,172			28,310

Total current liabilities		220,632			93,777

LONG-TERM AND OTHER LIABILITIES:
Deferred purchased power and fuel costs		23,656			10,665
Accumulated deferred income taxes		148,971			124,889
Accumulated deferred investment tax credits		19,333			20,792
Deferred credits and other liabilities		24,724			10,854

Total long-term and other liabilities		216,684			167,200

LONG-TERM DEBT, LESS CURRENT MATURITIES		174,495			342,411

COMMON SHAREHOLDER’S EQUITY:
Common shareholder’s equity:
Common stock, $10 par value per share
Authorized 12,000,000 shares; issued 10,705 shares		107			107
Capital in excess of par value		197,751			222,149
Retained earnings		54,516			115,685
Accumulated other comprehensive loss		(1,380	)		(530	)

Total common shareholder’s equity		250,994			337,411

COMMITMENTS AND CONTINGENCIES (Note 10)

	$	862,805		$	940,799

	Common Shareholder’s Equity
	Common Stock			Capital in Excess of Par Value			Retained Earnings			Accumulated Other Comprehensive Loss			Total
	Shares	Amount		Capital in Excess of Par Value			Retained Earnings			Accumulated Other Comprehensive Loss			Total
	*(Dollars in thousands)*
YEAR ENDED DECEMBER 31, 2000
Balance at January 1, 2000	10,705	$	107	$	222,149		$	90,302		$	—		$	312,558
Net income	—		—		—			41,957			—			41,957
Dividends on preferred stock	—		—		—			(51	)		—			(51	)
Dividends on common stock	—		—		—			(31,500	)		—			(31,500	)
Gain on retirement of preferred stock	—		—		—			13			—			13

Balance at December 31, 2000	10,705		107		222,149			100,721			—			322,977

YEAR ENDED DECEMBER 31, 2001
Net income	—		—		—			50,964			—			50,964
Dividends on common stock	—		—		—			(36,000	)		—			(36,000	)
Minimum pension liability	—		—		—			—			(530	)		(530	)

Balance at December 31, 2001	10,705		107		222,149			115,685			(530	)		337,411

YEAR ENDED DECEMBER 31, 2002
Comprehensive income
Net income	—		—		—			36,131			—			36,131
Other comprehensive income net of tax
Interest rate hedge	—		—		—			—			(1,164	)		(1,164	)
Minimum pension liability	—		—		—			—			314			314

Comprehensive income	—		—		—			36,131			(850	)		35,281
Dividends on common stock	—		—		—			(97,300	)		—			(97,300	)
Capitalization of First Choice Power	—		—		(24,398	)		—			—			(24,398	)

Balance at December 31, 2002	10,705	$	107	$	197,751		$	54,516		$	(1,380	)	$	250,994

	TNMP
	Before-Tax Amount			Tax Benefit (Expense)			After-Tax Amount
	*(In thousands)*
Interest rate hedge	$	(1,880	)	$	716		$	(1,164	)
Minimum pension liability		508			(194	)		314

	$	(1,372	)	$	522		$	(850	)

	December 31, 2002				December 31, 2001
	Carrying Amount		Fair Value		Carrying Amount		Fair Value
	*(In thousands)*
Capitalization and Liabilities
Long-term debt	$	346,000	$	337,688	$	343,000	$	332,500

	Pension Benefits						Postretirement Benefits
	2002			2001			2002			2001
	*(In thousands)*
Change in projected benefit obligation:
Benefit obligation at beginning of year	$	82,810		$	78,188		$	11,580		$	11,509
Service cost		2,321			2,406			345			394
Interest cost		5,564			5,716			732			831
Participant contributions		—			—			476			194
Actuarial (gain) or loss, including changes in
discount rate		3,422			3,381			(253	)		385
Benefits paid		(7,632	)		(6,881	)		(1,895	)		(1,733	)

Benefit obligation at end of year	$	86,485		$	82,810		$	10,985		$	11,580

Change in plan assets:
Fair value of plan assets at beginning of year	$	90,019		$	99,952		$	7,055		$	7,393
Actual return on plan assets, net of expenses		5,833			(3,213	)		(949	)		173
Employer contributions		—			—			865			1,019
Participant contributions		—			—			474			191
Benefits paid		(7,408	)		(6,720	)		(1,889	)		(1,721	)

Fair value of plan assets at end of year	$	88,444		$	90,019		$	5,556		$	7,055

	Pension Benefits									Postretirement Benefits
	2002			2001			2000			2002			2001			2000
	(In thousands)
Components of net periodic benefit cost
TNMP
Service cost	$	2,321		$	2,406		$	1,715		$	345		$	394		$	324
Interest cost		5,564			5,715			5,675			732			831			852
Expected return on plan assets		(7,722	)		(8,125	)		(7,654	)		(412	)		(442	)		(497	)
Amortization of prior service cost		(220	)		(220	)		(220	)		—			—			—
Amortization of transitional (asset) or obligation		—			—			(11	)		324			325			325
Recognized actuarial (gain) loss		193			1			(508	)		(126	)		(91	)		(192	)

TNMP net periodic benefit cost	$	136		$	(223	)	$	(1,003	)	$	863		$	1,017		$	812

Weighted-average assumptions as of December 31
Discount rate		6.50%			7.25%			7.50%			6.50%			7.25%			7.50%
Expected long-term rate of return on plan assets		9.00%			9.50%			9.50%			6.00%			6.00%			5.25%
Average rate of compensation increase		3.50%			4.00%			4.00%			N/A			N/A			N/A

	TNMP
	(In thousands)
Minimum tax credits
Amount	$	19,028
Expiration period		None

Year	TNMP/ First Choice Credit Facility
	(In thousands)
2003	$	171,000
2004		—
2005		—
2006		—
2007		—

	March 31		June 30		Sept. 30		Dec. 31
	(In thousands)
2002
Operating revenues	$	77,578	$	76,568	$	86,367	$	63,394
Operating income		15,894		18,989		25,563		16,201
Income before the cumulative effect of change in accounting		7,125		9,034		13,103		6,869
Net income		7,125		9,034		13,103		6,869

	March 31		June 30		Sept. 30		Dec. 31
	(In thousands)
2001
Operating revenues	$	168,354	$	161,335	$	185,834	$	136,009
Operating income		18,388		24,060		43,450		18,919
Income before the cumulative effect of change in accounting		7,886		11,266		23,706		9,276
Net income		6,716		11,266		23,706		9,276

	Three Months Ended September 30,						Nine Months Ended September 30,
	2003			2002			2003			2002
	(In thousands)
OPERATING REVENUES:
Affiliated	$	29,899		$	32,607		$	83,816		$	80,689
Non-affiliated		40,054			53,760			115,263			159,824

Total operating revenues		69,953			86,367			199,079			240,513

OPERATING EXPENSES:
Purchased power and fuel		17,542			26,588			50,843			83,093
Other operating and maintenance		13,554			20,402			47,544			57,233
Depreciation of utility plant		7,197			6,795			21,374			20,725
Credit for recovery of stranded plant		—			—			—			(733	)
Taxes other than income taxes		5,976			7,019			16,088			19,749

Total operating expenses		44,269			60,804			135,849			180,067

OPERATING INCOME		25,684			25,563			63,230			60,446

INTEREST CHARGES AND OTHER INCOME AND DEDUCTIONS:
Interest on long-term debt		6,592			4,579			18,670			13,883
Other interest and amortization of debt-related costs		277			946			1,977			2,686
Other income and deductions, net		(783	)		(60	)		(1,631	)		(315	)

Total		6,086			5,465			19,016			16,254

INCOME BEFORE INCOME TAXES		19,598			20,098			44,214			44,192
Income taxes		7,295			6,995			16,031			14,930

NET INCOME	$	12,303		$	13,103		$	28,183		$	29,262

	September 30,			December 31,
	2003			2002
	(In thousands)
*ASSETS*
CURRENT ASSETS:
Cash and cash equivalents	$	65,218		$	284
Accounts receivable
Affiliated		13,384			16,633
Non-affiliated		17,304			17,045
Materials and supplies, at lower of cost or market		1,040			992
Deferred purchased power costs		—			1,320
Accumulated deferred income taxes		70			70
Other current assets		979			612

Total current assets		97,995			36,956

UTILITY PLANT:
Electric plant		792,213			770,960
Construction work in progress		13,800			11,707

Total		806,013			782,667
Less accumulated depreciation		294,697			278,757

Net utility plant		511,316			503,910

LONG-TERM AND OTHER ASSETS:
Other property and investments, at cost		343			343
Recoverable stranded costs		298,748			298,748
Regulatory tax assets		1,423			913
Deferred charges		27,577			21,935

Total long-term and other assets		328,091			321,939

	$	937,402		$	862,805

*LIABILITIES AND SHAREHOLDER’S EQUITY*
CURRENT LIABILITIES:
Current maturities of long-term debt	$	—		$	171,000
Notes payable to affiliate		—			14,557
Accounts payable		8,664			9,543
Accrued interest		7,000			5,345
Accrued taxes		10,453			9,923
Customers’ deposits		685			1,092
Deferred purchased power costs		528			—
Other current liabilities		16,678			9,172

Total current liabilities		44,008			220,632

LONG-TERM AND OTHER LIABILITIES:
Deferred purchased power and fuel costs		24,321			23,656
Accumulated deferred income taxes		154,144			148,971
Accumulated deferred investment tax credits		18,698			19,333
Deferred credits and other liabilities		24,142			24,724

Total long-term and other liabilities		221,305			216,684

LONG-TERM DEBT, LESS CURRENT MATURITIES		423,552			174,495

COMMON SHAREHOLDER’S EQUITY:
Common stock, $10 par value per share
Authorized 12,000,000 shares; issued 10,705 shares		107			107
Capital in excess of par value		197,751			197,751
Retained earnings		53,299			54,516
Accumulated other comprehensive loss		(2,620	)		(1,380	)

Total common shareholder’s equity		248,537			250,994

COMMITMENTS AND CONTINGENCIES (Note 7)

	$	937,402		$	862,805

	Three Months Ended September 30, 2003						Nine Months Ended September 30, 2003
	Before-Tax Amount		Tax Benefit (Expense)		After-Tax Amount		Before-Tax Amount			Tax Benefit (Expense)			After-Tax Amount
	(In thousands)
Change in market value	$	—	$	—	$	—	$	(5,922	)	$	2,256		$	(3,666	)
Reclassification adjustments		208		(79)		129		3,919			(1,493	)		2,426

Other comprehensive income (loss)	$	208	$	(79)	$	129	$	(2,003	)	$	763		$	(1,240	)

	Title	Date

/s/ Jack V. Chambers Jack V. Chambers	Chairman, President & Chief Executive Officer of TNMP	~~November 26,~~December 8, 2003

/s/ William J. Catacosinos William J. Catacosinos	Director	~~November 26,~~December 8, 2003

/s/ James T. Flynn James T. Flynn	Director	~~November 26,~~December 8, 2003

/s/ Preston M. Geren, III Preston M. Geren, III	Director	~~November 26,~~December 8, 2003

/s/ Leeam Lowin Leeam Lowin	Director	~~November 26,~~December 8, 2003

Exhibit No.		Description

3(i)		Amended and Restated Articles of Incorporation. (Ex. 3(b)(i), TNMP Form 10-Q, quarter ended March 31, 2000).

3(ii)		Amended and Restated Bylaws.

3(iii)		Articles of Amendment filed April 25, 2001. (Ex. 3, TNMP Form 10-Q, quarter ended June 30, 2001).

3(iv)		Articles of Amendment filed August 16, 2001. (Ex. 3(iv), TNMP 2001 Form 10-K)

4(a)		Indenture dated Jan. 1, 1999 between TNMP and the Chase Bank of Texas, N. A. (Ex. 4(w), TNMP 1998 Form 10-K).

4(b)		First Supplemental Indenture dated Jan. 1, 1999 to Indenture dated Jan. 1, 1999 between TNMP and the Chase Bank of Texas, N. A. (Ex. 4(x), TNMP 1998 Form 10-K).

4(c)		Second Supplemental Indenture dated June 1, 2003, to Indenture dated Jan. 1, 1999 between TNMP and JPMorgan Bank (successor to The Chase Bank of Texas, N.A.) (Ex. 4, TNMP Form 10-Q, quarter ended June 30, 2003)

4(d)		Registration Rights Agreement dated June 10, 2003 among TNMP and the Initial Purchasers named therein.

*5(a)		Opinion of Kramer Levin Naftalis & Frankel, LLP regarding legality of securities to be registered.

*5(b)		Opinion of Paul W. Talbot, Senior Counsel to TNMP.

10(a)		Contract dated April 29, 1987, between TNMP and El Paso Electric Company (Ex. 10(f), Form 8 applicable to TNMP 1986 Form 10-K).

10(b)		Interconnection Agreement between TNMP and Plains Electric Generation and Transmission Cooperative, Inc. dated July 19, 1984 (Ex. 10(j), Form 8 applicable to TNMP 1986 Form 10-K).

10(c)		Interchange Agreement between TNMP and El Paso Electric Company dated April 29, 1987 (Ex. 10(l), Form 8 applicable to TNMP 1986 Form 10-K).

10(d)		Amendment No. 1, dated Nov. 21, 1994, to Interchange Agreement between TNMP and El Paso Electric Company (Ex. 10(nn)1, TNP and TNMP 1994 Form 10-K).

10(e)		DC Terminal Participation Agreement between TNMP and El Paso Electric Company dated Dec. 8, 1981 as amended (Ex. 10(m), Form 8 applicable to TNMP 1986 Form 10-K).

10(f)+		Agreements dated April 8, 2001, and April 16, 2001 between Jack V. Chambers and TNMP (Ex. 10(j), TNMP 2001 Form 10-K).

10(g)+		Agreement dated April 6, 2000 between W. Douglas Hobbs and TNMP. (Ex. 10(r), TNMP 2000 Form 10-K).

10(g)(1)+		Amendment dated August 5, 2002 to Agreement dated April 6, 2000 between W. Douglas Hobbs and TNMP. (Ex. 10(j)(1), TNMP 2002 10-K)

10(h)+		Form of Change in Control Agreement between TNMP and each of Jack V. Chambers, Scott Forbes, W. Douglas Hobbs, Michael D. Blanchard, and Melissa D. Davis.

10(i)+		Agreement dated April 6, 2000 between Michael D. Blanchard and TNMP (Ex. 10(k), TNMP 2002 Form 10-K)

10(j)+		Agreement dated April 6, 2000 between Melissa D. Davis and TNMP (Ex. 10(l), TNMP 2002 Form 10-K)

10(k)		Wholesale Requirements Power Sale and Services Agreement Between Public Service Company of New Mexico and Texas-New Mexico Power Company dated June 29, 2001.

*12		Statements re computation of ratios.

21		Subsidiaries of the Registrants.

*23(a)		Consent of Deloitte & Touche LLP

*23(b)		Consent of Kramer Levin Naftalis & Frankel, LLP (included in the opinion filed as Exhibit 5(a) to this registration statement).

*23(c)		Consent of Paul W. Talbot (included in opinion filed as Exhibit 5(b) to this registration statement.

24		Power of Attorney (included on the signature pages of this registration statement).

25		Statement of Eligibility of Trustee on Form T-1 of JPMorgan Chase Bank.

99(a)		Final Order of the New Mexico Public Regulation Commission dated January 18, 2000 In the Matter of the Application of Texas-New Mexico Power Company for Approvals and Authorizations to (i) Acquire the Stock of TNP Enterprises, Inc., (ii) Form Additional Public Utility Holding Companies, (iii) Amend its General Diversification Plan, (iv) Issue Debt Securities,, and (v) Obtain All Other Approvals and Authorizations Necessary to Effectuate and Consummate the Transactions, Texas-New Mexico Power Company, Applicant, Utility Case No. 3103.

99(b)		Revised Joint Stipulation and Agreement approved by Final Order of the Public Utility Commission of Texas in Application of Texas-New Mexico Power Company and TNP Enterprises, Inc. Regarding Merger of TNP Enterprises, Inc. and ST Acquisition Corp., PUC Docket No. 21112, SOAH Docket No. 473-99-1483, dated February 22, 2000.

*99(c)		Form of Letter of Transmittal.