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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 


 

Form 10-Q

 

(Mark One)

 

  x QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
       For the quarterly period ended June 30, 2004

 

OR

 

  ¨ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
       For the transition period from ____ to ____

 

Commission file number 0-296

 

El Paso Electric Company

(Exact name of registrant as specified in its charter)

 

Texas   74-0607870
(State or other jurisdiction of incorporation or organization)   (I.R.S. Employer Identification No.)

 

Stanton Tower, 100 North Stanton, El Paso, Texas   79901
(Address of principal executive offices)   (Zip Code)

 

(915) 543-5711

(Registrant’s telephone number, including area code)

 

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

 

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

 

As of August 2, 2004, there were 47,591,765 shares of the Company’s no par value common stock outstanding.

 



Table of Contents

 

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

 

INDEX TO FORM 10-Q

 

     Page No.

PART I. FINANCIAL INFORMATION

    

Item 1. Financial Statements

    

Consolidated Balance Sheets – June 30, 2004 and December 31, 2003

   1

Consolidated Statements of Operations – Three Months, Six Months and Twelve Months Ended June 30, 2004 and 2003

   3

Consolidated Statements of Comprehensive Operations – Three Months, Six Months and Twelve Months Ended June 30, 2004 and 2003

   5

Consolidated Statements of Cash Flows – Six Months Ended June 30, 2004 and 2003

   6

Notes to Consolidated Financial Statements

   7

Report of Independent Registered Public Accounting Firm

   22

Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

   23

Item 3. Quantitative and Qualitative Disclosures About Market Risk

   33

Item 4. Controls and Procedures

   33

PART II. OTHER INFORMATION

    

Item 1. Legal Proceedings

   34

Item 2. Changes in Securities, Use of Proceeds and Issuer Purchases of Equity Securities

   34

Item 4. Submission of Matters to a Vote of Security Holders

   34

Item 6. Exhibits and Reports on Form 8-K

   35

 

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Table of Contents

PART I. FINANCIAL INFORMATION

 

Item 1. Financial Statements

 

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED BALANCE SHEETS

 

ASSETS

(In thousands)

   June 30,
2004
(Unaudited)


   December 31,
2003


Utility plant:

             

Electric plant in service

   $ 1,805,052    $ 1,784,134

Less accumulated depreciation and amortization

     629,944      591,613
    

  

Net plant in service

     1,175,108      1,192,521

Construction work in progress

     74,681      69,175

Nuclear fuel; includes fuel in process of $6,580 and $6,878, respectively

     69,385      70,198

Less accumulated amortization

     33,633      33,888
    

  

Net nuclear fuel

     35,752      36,310
    

  

Net utility plant

     1,285,541      1,298,006
    

  

Current assets:

             

Cash and temporary investments

     26,928      34,426

Accounts receivable, principally trade, net of allowance for doubtful accounts of $3,547 and $3,470, respectively

     71,436      66,589

Accumulated deferred income taxes

     23,386      36,248

Inventories, at cost

     25,162      25,321

Undercollection of fuel revenues

     11,591      12,399

Prepayments and other

     29,725      27,190
    

  

Total current assets

     188,228      202,173
    

  

Deferred charges and other assets:

             

Decommissioning trust funds

     83,470      80,475

Other

     12,976      15,200
    

  

Total deferred charges and other assets

     96,446      95,675
    

  

Total assets

   $ 1,570,215    $ 1,595,854
    

  

 

See accompanying notes to consolidated financial statements.

 

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Table of Contents

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED BALANCE SHEETS (Continued)

 

CAPITALIZATION AND LIABILITIES

(In thousands except for share data)

   June 30,
2004
(Unaudited)


    December 31,
2003


 

Capitalization:

                

Common stock, stated value $1 per share, 100,000,000 shares authorized, 62,606,097 and 62,487,263 shares issued, and 104,920 and 146,489 restricted shares, respectively

   $ 62,711     $ 62,633  

Capital in excess of stated value

     265,283       264,235  

Unearned compensation – restricted stock awards

     (1,102 )     (878 )

Retained earnings

     365,753       354,993  

Accumulated other comprehensive loss, net of tax

     (10,515 )     (9,613 )
    


 


       682,130       671,370  

Treasury stock, 15,120,266 and 15,070,266 shares respectively; at cost

     (172,294 )     (171,548 )
    


 


Common stock equity

     509,836       499,822  

Long-term debt, net of current portion

     563,071       588,536  

Financing obligations, net of current portion

           20,186  
    


 


Total capitalization

     1,072,907       1,108,544  
    


 


Current liabilities:

                

Current portion of long-term debt and financing obligations

     42,003       22,106  

Accounts payable, principally trade

     30,301       19,197  

Taxes accrued other than federal income taxes

     13,919       15,167  

Interest accrued

     14,088       14,706  

Overcollection of fuel revenues

     851       10,070  

Other

     18,818       20,781  
    


 


Total current liabilities

     119,980       102,027  
    


 


Deferred credits and other liabilities:

                

Accumulated deferred income taxes

     125,295       139,605  

Accrued postretirement benefit liability

     98,007       94,510  

Asset retirement obligation

     57,768       55,149  

Accrued pension liability

     54,225       53,000  

Other

     42,033       43,019  
    


 


Total deferred credits and other liabilities

     377,328       385,283  
    


 


Commitments and contingencies

                

Total capitalization and liabilities

   $ 1,570,215     $ 1,595,854  
    


 


 

See accompanying notes to consolidated financial statements.

 

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Table of Contents

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands except for share data)

 

     Three Months Ended
June 30,


    Six Months Ended
June 30,


 
     2004

    2003

    2004

    2003

 

Operating revenues

   $ 182,206     $ 162,498     $ 338,058     $ 309,984  
    


 


 


 


Energy expenses:

                                

Fuel

     47,804       37,901       86,853       70,252  

Purchased and interchanged power

     21,742       13,855       34,594       26,631  
    


 


 


 


       69,546       51,756       121,447       96,883  
    


 


 


 


Operating revenues net of energy expenses

     112,660       110,742       216,611       213,101  
    


 


 


 


Other operating expenses:

                                

Other operations

     41,369       42,988       82,581       82,305  

Maintenance

     10,751       15,707       19,954       30,770  

Depreciation and amortization

     23,127       21,735       46,186       43,097  

Taxes other than income taxes

     10,956       11,017       22,493       22,100  
    


 


 


 


       86,203       91,447       171,214       178,272  
    


 


 


 


Operating income

     26,457       19,295       45,397       34,829  
    


 


 


 


Other income (deductions):

                                

Investment and interest income, net

     441       397       712       527  

Loss on extinguishments of debt

     (1,732 )           (3,838 )     (1 )

Miscellaneous other income

     233       183       298       211  

Miscellaneous income deductions

     (1,020 )     (355 )     (1,984 )     (1,144 )
    


 


 


 


       (2,078 )     225       (4,812 )     (407 )
    


 


 


 


Interest charges (credits):

                                

Interest on long-term debt and financing obligations

     12,306       12,795       24,979       25,891  

Other interest

     139       90       287       189  

Interest capitalized

     (821 )     (1,349 )     (1,591 )     (2,665 )
    


 


 


 


       11,624       11,536       23,675       23,415  
    


 


 


 


Income before income taxes and cumulative effect of accounting change

     12,755       7,984       16,910       11,007  

Income tax expense

     4,982       2,989       6,150       3,896  
    


 


 


 


Income before cumulative effect of accounting change

     7,773       4,995       10,760       7,111  

Cumulative effect of accounting change, net of tax

                       39,635  
    


 


 


 


Net income

   $ 7,773     $ 4,995     $ 10,760     $ 46,746  
    


 


 


 


Basic earnings per share:

                                

Income before cumulative effect of accounting change

   $ 0.16     $ 0.10     $ 0.23     $ 0.15  

Cumulative effect of accounting change, net of tax

                       0.80  
    


 


 


 


Net income

   $ 0.16     $ 0.10     $ 0.23     $ 0.95  
    


 


 


 


Diluted earnings per share:

                                

Income before cumulative effect of accounting change

   $ 0.16     $ 0.10     $ 0.22     $ 0.15  

Cumulative effect of accounting change, net of tax

                       0.80  
    


 


 


 


Net income

   $ 0.16     $ 0.10     $ 0.22     $ 0.95  
    


 


 


 


Weighted average number of shares outstanding

     47,500,257       48,659,155       47,475,778       48,981,211  
    


 


 


 


Weighted average number of shares and dilutive potential shares outstanding

     47,966,465       49,037,673       47,933,383       49,327,186  
    


 


 


 


 

See accompanying notes to consolidated financial statements.

 

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Table of Contents

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

(In thousands except for share data)

    

Twelve Months Ended

June 30,


 
     2004

    2003

 

Operating revenues

   $ 692,436     $ 669,850  
    


 


Energy expenses:

                

Fuel

     181,968       140,267  

Purchased and interchanged power

     63,555       79,231  
    


 


       245,523       219,498  
    


 


Operating revenues net of energy expenses

     446,913       450,352  
    


 


Other operating expenses:

                

Other operations

     167,773       164,480  

FERC settlements

           15,500  

Impairment loss on CIS project

     17,576        

Maintenance

     37,430       56,308  

Depreciation and amortization

     90,230       87,670  

Taxes other than income taxes

     43,121       43,473  
    


 


       356,130       367,431  
    


 


Operating income

     90,783       82,921  
    


 


Other income (deductions):

                

Investment and interest income (loss), net

     2,025       (640 )

Loss on extinguishments of debt

     (3,838 )     (1 )

Miscellaneous other income

     475       698  

Miscellaneous income deductions

     (2,724 )     (2,892 )
    


 


       (4,062 )     (2,835 )
    


 


Interest charges (credits):

                

Interest on long-term debt and financing obligations

     50,488       53,167  

Other interest

     793       4,647  

Interest capitalized

     (4,498 )     (5,347 )
    


 


       46,783       52,467  
    


 


Income before income taxes and cumulative effect of accounting change

     39,938       27,619  

Income tax expense

     15,673       9,710  
    


 


Income before cumulative effect of accounting change

     24,265       17,909  

Cumulative effect of accounting change, net of tax

           39,635  
    


 


Net income

   $ 24,265     $ 57,544  
    


 


Basic earnings per share:

                

Income before cumulative effect of accounting change

   $ 0.51     $ 0.36  

Cumulative effect of accounting change, net of tax

           0.81  
    


 


Net income

   $ 0.51     $ 1.17  
    


 


Diluted earnings per share:

                

Income before cumulative effect of accounting change

   $ 0.50     $ 0.36  

Cumulative effect of accounting change, net of tax

           0.80  
    


 


Net income

   $ 0.50     $ 1.16  
    


 


Weighted average number of shares outstanding

     47,677,134       49,335,156  
    


 


Weighted average number of shares and dilutive potential shares outstanding

     48,123,497       49,727,209  
    


 


 

See accompanying notes to consolidated financial statements.

 

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Table of Contents

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF COMPREHENSIVE OPERATIONS

(Unaudited)

(In thousands)

 

    

Three Months

Ended
June 30,


   

Six Months

Ended
June 30,


   

Twelve Months

Ended
June 30,


 
     2004

    2003

    2004

    2003

    2004

    2003

 

Net income

   $ 7,773     $ 4,995     $ 10,760     $ 46,746     $ 24,265     $ 57,544  

Other comprehensive income (loss):

                                                

Minimum pension liability adjustment

                             (4,234 )     (21,148 )

Net unrealized gains (losses) on marketable securities:

                                                

Net holding gains (losses) arising during period

     (1,066 )     5,322       (779 )     4,137       3,848       1,204  

Reclassification adjustments for net (gains) losses included in net income

     (115 )     130       (348 )     796       (422 )     3,617  
    


 


 


 


 


 


Total other comprehensive income (loss) before income taxes

     (1,181 )     5,452       (1,127 )     4,933       (808 )     (16,327 )
    


 


 


 


 


 


Income tax benefit (expense) related to items of other comprehensive income (loss):

                                                

Minimum pension liability adjustment

                             1,673       8,216  

Net unrealized gains (losses) on marketable securities

     236       (1,908 )     225       (1,727 )     (165 )     (1,687 )
    


 


 


 


 


 


Total income tax benefit (expense)

     236       (1,908 )     225       (1,727 )     1,508       6,529  
    


 


 


 


 


 


Other comprehensive income (loss), net of tax

     (945 )     3,544       (902 )     3,206       700       (9,798 )
    


 


 


 


 


 


Comprehensive income

   $ 6,828     $ 8,539     $ 9,858     $ 49,952     $ 24,965     $ 47,746  
    


 


 


 


 


 


 

See accompanying notes to consolidated financial statements.

 

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Table of Contents

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

(In thousands)

    

Six Months Ended

June 30,


 
     2004

    2003

 

Cash flows from operating activities:

                

Net income

   $ 10,760     $ 46,746  

Adjustments to reconcile net income to net cash provided by operating activities:

                

Depreciation and amortization of electric plant in service

     46,186       43,097  

Amortization of nuclear fuel

     8,193       8,470  

Cumulative effect of accounting change, net of tax

           (39,635 )

Deferred income taxes, net

     (991 )     (2,901 )

Loss on extinguishments of debt

     3,838       1  

Other amortization and accretion

     4,456       3,929  

Other operating activities

     1       1,422  

Change in:

                

Accounts receivable

     (4,847 )     (7,261 )

Inventories

     71       621  

Net (under)/overcollection of fuel revenues

     (8,411 )     9,381  

Prepayments and other

     (3,573 )     (136 )

Accounts payable

     11,104       710  

Taxes accrued other than federal income taxes

     (1,248 )     (2,504 )

Interest accrued

     (618 )     (1,302 )

Other current liabilities

     (1,963 )     1,688  

Deferred charges and credits

     4,653       2,835  
    


 


Net cash provided by operating activities

     67,611       65,161  
    


 


Cash flows from investing activities:

                

Cash additions to utility property, plant and equipment

     (30,010 )     (32,735 )

Cash additions to nuclear fuel

     (7,602 )     (6,660 )

Interest capitalized:

                

Utility property, plant and equipment

     (1,476 )     (2,523 )

Nuclear fuel

     (115 )     (142 )

Decommissioning trust funds:

                

Purchases, includes funding of $3.0 million and $7.6 million, respectively

     (9,392 )     (11,501 )

Sales and maturities

     5,272       3,469  

Other investing activities

     (1,755 )     1,238  
    


 


Net cash used for investing activities

     (45,078 )     (48,854 )
    


 


Cash flows from financing activities:

                

Proceeds from exercise of stock options

     305        

Repurchases of common stock

     (746 )     (16,728 )

Repurchases of and payments on first mortgage bonds

     (29,067 )     (39,360 )

Nuclear fuel financing obligations:

                

Proceeds

     8,198       7,367  

Payments

     (8,465 )     (9,704 )

Other financing activities

     (256 )     (309 )
    


 


Net cash used for financing activities

     (30,031 )     (58,734 )
    


 


Net decrease in cash and temporary investments

     (7,498 )     (42,427 )

Cash and temporary investments at beginning of period

     34,426       75,142  
    


 


Cash and temporary investments at end of period

   $ 26,928     $ 32,715  
    


 


 

See accompanying notes to consolidated financial statements.

 

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Table of Contents

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 

(Unaudited)

 

A. Principles of Preparation

 

These condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and notes thereto in the Annual Report of El Paso Electric Company on Form 10-K for the year ended December 31, 2003 (the “2003 Form 10-K”). Capitalized terms used in this report and not defined herein have the meaning ascribed for such terms in the 2003 Form 10-K. In the opinion of management of the Company, the accompanying consolidated financial statements contain all adjustments necessary to present fairly the financial position of the Company at June 30, 2004 and December 31, 2003; the results of its operations and comprehensive operations for the three, six and twelve months ended June 30, 2004 and 2003; and its cash flows for the six months ended June 30, 2004 and 2003. The results of operations and comprehensive operations for the three and six months ended June 30, 2004 and the cash flows for the six months ended June 30, 2004 are not necessarily indicative of the results to be expected for the full calendar year.

 

Pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”), certain financial information has been condensed and certain footnote disclosures have been omitted. Such information and disclosures are normally included in annual financial statements prepared in accordance with generally accepted accounting principles. Certain prior period amounts primarily related to the presentation of energy service operation revenues and expenses have been reclassified to conform with the current period presentation.

 

At January 1, 2004, the Company adopted FASB Interpretation No. 46 (“FIN 46R”), “Consolidation of Variable Interest Entities,” which addresses how a business enterprise should evaluate whether it has a controlling financial interest in an entity through means other than voting rights and accordingly should consolidate the entity. As of June 30, 2004, the Company has had no transactions that have established a variable interest entity and the implementation of this standard did not have an impact on the Company’s financial position or results of operations.

 

SFAS No. 71. The Company discontinued the application of SFAS No. 71, “Accounting for the Effects of Certain Types of Regulation,” to its financial statements in 1991 and is currently evaluating whether it meets the criteria for reapplication of SFAS No. 71 to some or all of its business.

 

Stock Options and Restricted Stock. The Company has two stock-based long-term incentive plans and accounts for them under the recognition and measurement principles of APB Opinion No. 25, “Accounting for Stock Issued to Employees,” and related interpretations. Stock options have typically been granted with an exercise price equal to fair market value on the date of grant and, accordingly, no compensation expense is recorded by the Company. Restricted stock has been granted at fair market value. Accordingly, the Company recognizes compensation expense by ratably amortizing the fair market value of the grant of restricted stock over the restriction period. If compensation expense for the option portion of the plans had been determined based on the fair value of the option at the grant date and amortized on a straight-line basis over the vesting period, consistent with the provisions of SFAS

 

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Table of Contents

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 

(Unaudited)

 

No. 123, “Accounting for Stock-Based Compensation,” the Company’s net earnings and earnings per share would have been reduced to the pro forma amounts presented below:

 

     Three Months
Ended June 30,


   Six Months
Ended June 30,


     2004

   2003

   2004

   2003

Net income, as reported

   $ 7,773    $ 4,995    $ 10,760    $ 46,746

Deduct: Compensation expense, net of tax

     229      228      458      459
    

  

  

  

Pro forma net income

   $ 7,544    $ 4,767    $ 10,302    $ 46,287
    

  

  

  

Basic earnings per share:

                           

As reported

   $ 0.16    $ 0.10    $ 0.23    $ 0.95

Pro forma

     0.16      0.10      0.22      0.95

Diluted earnings per share:

                           

As reported

     0.16      0.10      0.22      0.95

Pro forma

     0.16      0.10      0.22      0.94

 

     Twelve Months
Ended June 30,


     2004

   2003

Net income, as reported

   $ 24,265    $ 57,544

Deduct: Compensation expense, net of tax

     916      1,184
    

  

Pro forma net income

   $ 23,349    $ 56,360
    

  

Basic earnings per share:

             

As reported

   $ 0.51    $ 1.17

Pro forma

     0.49      1.14

Diluted earnings per share:

             

As reported

     0.50      1.16

Pro forma

     0.49      1.14

 

Compensation expense for the restricted stock awards is recognized on a fair value basis and is measured by referencing the quoted market price of the shares at the grant date, amortized ratably over the restriction period. Unearned compensation related to restricted stock awards is shown as a reduction of common stock equity and is the remaining unamortized portion of the restricted stock awards.

 

Unbilled Revenues. Accounts receivable includes accrued unbilled revenues of $18.2 million and $16.5 million at June 30, 2004 and December 31, 2003, respectively.

 

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Table of Contents

EL PASO ELECTRIC COMPANY AND SUBSIDIARY

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 

(Unaudited)

 

Supplemental Cash Flow Disclosures (in thousands)

 

     Six Months Ended June 30,

     2004

   2003

Cash paid for:

             

Interest on long-term debt and financing obligations

   $ 25,001    $ 26,659

Income taxes

     7,150      2,100

Non-cash financing activities:

             

Grants of restricted shares of common stock

     776      669

 

B. Regulation

 

For a full discussion of the Company’s regulatory matters, see Note B of Notes to Consolidated Financial Statements in the 2003 Form 10-K.

 

General

 

In 1999, both the Texas and New Mexico legislatures enacted electric utility industry restructuring laws requiring competition in certain functions of the industry and ultimately in the Company’s service area. In Texas, the Company is exempt from the requirements of the Texas Restructuring Law, including utility restructuring and retail competition, at least until the expiration of the Freeze Period in August 2005. In April 2003, the New Mexico Restructuring Act was repealed and as a result, the Company’s operations in New Mexico will continue to be fully regulated. The Company cannot predict at this time the full effects the repeal of the New Mexico Restructuring Act will have on the Company as it prepares for retail competition in Texas.

 

Federal Regulatory Matters

 

Federal Energy Regulatory Commission. The FERC has been conducting an investigation into potential manipulation of electricity prices in the western United States during 2000 and 2001. On August 13, 2002, the FERC initiated a Federal Power Act (“FPA”) investigation into the Company’s wholesale power trading in the western United States during 2000 and 2001 to determine whether the Company and Enron engaged in misconduct and, if so, to determine potential remedies. The Company reached settlements with the FERC and other parties in 2002 and 2003. Under the terms of the settlements, the Company agreed to refund a total of $15.5 million of revenues it earned on wholesale power transactions. In July 2003, the FERC approved the settlements and on August 5, 2003, the Company deposited the $15.5 million into an interest bearing escrow account to consummate the settlements. The Company believes the FERC’s order resolved all issues between the FERC and the other parties to this investigation. Under the settlements, the Company has agreed to make wholesale sales pursuant to its cost of service rate authority rather than its market-based rate authority for the

 

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period December 1, 2002 through December 31, 2004. This agreement allows the Company to sell power into wholesale markets at its incremental cost plus $21.11 per MWh. To the extent that wholesale market prices exceed these agreed upon amounts, the Company will forego the opportunity to realize these additional revenues. Although this provision has not had a significant impact on the Company’s revenues through June 30, 2004, the Company is unable to predict the effect, if any, this will have on the Company’s revenues for the remainder of 2004.

 

Texas Regulatory Matters

 

The rates and services of the Company are regulated in Texas by municipalities and by the Texas Commission. The largest municipality in the Company’s service area is the City of El Paso. The Texas Commission has exclusive appellate jurisdiction to review municipal orders and ordinances regarding rates and services within municipalities in Texas and original jurisdiction over certain other activities of the Company. The decisions of the Texas Commission are subject to judicial review.

 

Deregulation. The Texas Restructuring Law required certain investor-owned electric utilities to separate power generation activities from transmission and distribution activities by January 1, 2002, and on that date, retail competition was instituted in some parts of Texas. The Texas Restructuring Law, however, specifically recognized and preserved the Company’s Texas Rate Stipulation and Texas Settlement Agreement by, among other things, exempting the Company’s Texas service area from retail competition until the end of the Freeze Period. The Texas Commission opened a project (Project No. 28971) to evaluate the readiness of the Company’s service area in Texas for retail competition. In this project, the Texas Commission may specify in advance the factors that are important in deciding when and how to open the Company’s service area in Texas to customer choice. The Texas Commission has published and taken comments from interested parties on a proposed rule. The proposed rule sets forth a process and sequence of events for the introduction of retail competition in the Company’s service territory. The proposed sequence of events is based upon completion of the specific items in each stage before the next stage is initiated. Based on the Texas Commission’s proposed rule, the first event that must occur before the introduction of competition in the Company’s service territory is the creation of an operating regional transmission organization. If the proposed rule is adopted in its present form, the Company believes that retail competition in the El Paso area would likely not begin for several years. The Texas Commission is expected to issue its final rule before the end of 2004. There is substantial uncertainty about both the regulatory framework and market conditions that will exist if and when retail competition is implemented in the Company’s service territory and the Company may incur substantial preparatory, restructuring and other costs that may not ultimately be recoverable. There can be no assurance that deregulation will not adversely affect the future operations, cash flows and financial condition of the Company.

 

Fuel. Although the Company’s base rates are frozen in Texas pursuant to Texas Commission rules and the Texas Rate Stipulation, the Company can request adjustments to its fuel factor to more accurately reflect projected energy costs associated with providing electricity and seek recovery of past

 

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undercollections of fuel revenues, subject to periodic final review by the Texas Commission in fuel reconciliation proceedings.

 

The Company reconciled its Texas jurisdictional fuel costs for the period January 1, 1999 through December 31, 2001 in PUC Docket No. 26194, and on May 5, 2004, the Texas Commission issued its final order. At issue was the Company’s request to recover an additional $15.8 million, before interest, from its Texas customers as a surcharge because of fuel undercollections from January 1999 through December 2001. The Texas Commission disallowed approximately $4.5 million of Texas jurisdictional expenses, before interest, consisting primarily of (i) approximately $4.2 million of purchased power expenses which the Texas Commission characterized as “imputed capacity charges,” and (ii) approximately $0.3 million in fees which were deemed to be administrative costs, not recoverable as fuel. In Texas, capacity charges are not eligible for recovery as fuel expenses, but are to be recovered through the Company’s base rates. As the Company’s base rates were frozen during the time period in which the imputed capacity charges were deemed to have been incurred, the $4.2 million of imputed capacity charges would be permanently disallowed, and not recoverable from its Texas customers. The Texas Commission’s decision has been appealed by two parties and the Company, and the Company is unable to predict the ultimate outcome of the appeals.

 

The Company has incurred similar purchased power costs for the fuel reconciliation period beginning January 1, 2002. The Company believes that it has accounted for its purchased power costs during the reconciliation period beginning January 2002 in a manner consistent with the Texas Commission’s decision in PUC Docket No. 26194. However, the Texas Commission has indicated its desire to conduct a generic rulemaking proceeding to determine a statewide policy for the appropriate pricing of capacity in purchased power contracts. There can be no assurance as to the outcome of such rulemaking and its potential impact on the Company with respect to fuel recovery in future reconciliation periods.

 

New Mexico Regulatory Matters

 

The New Mexico Commission has jurisdiction over the Company’s rates and services in New Mexico and over certain other activities of the Company, including prior approval of the issuance, assumption or guarantee of securities. The New Mexico Commission’s decisions are subject to judicial review. The largest city in the Company’s New Mexico service territory is Las Cruces.

 

Deregulation. In April 2003, the New Mexico Restructuring Act was repealed and as a result the Company’s operations in New Mexico will continue to be fully regulated. The Company cannot predict at this time the full effects the repeal of the New Mexico Restructuring Act will have on the Company if it ultimately transitions to retail competition in Texas.

 

New Mexico Rate Stipulation. On June 1, 2004, the Company implemented new rates according to the New Mexico Stipulation whereby, among other things, the Company agreed for a period of three years beginning June 1, 2004 to (i) freeze base rates after an initial non-fuel base rate reduction of 1%;

 

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(ii) fix fuel and purchased power cost associated with 10% of the Company’s jurisdictional retail sales in New Mexico at $0.021 per kWh; (iii) leave subject to reconciliation the remaining 90% of the Company’s New Mexico jurisdictional fuel and purchased power costs not collected in base rates; (iv) continue the collection of a portion of fuel and purchased power costs in base rates as presently collected in the amount of $0.01949 per kWh; (v) price power provided from Palo Verde Unit 3 to the extent of its availability at an 80% nuclear, 20% gas fuel mix (previously such power was priced at 75% nuclear, 25% gas fuel mix); and (vi) deem reconciled, for the period June 15, 2001 through May 31, 2004, the Company’s fuel and purchased power costs for the New Mexico jurisdiction.

 

Fuel. In April 2004, the New Mexico Commission, as part of the New Mexico Stipulation, approved a fuel and purchased power cost adjustment clause. The Company will continue to recover fuel and purchased power costs in base rates in the amount of $0.01949 per kWh and continue the fuel and purchased power cost adjustment to recover 90% of the remaining fuel and purchased power costs. Fuel and purchased power costs associated with the remaining 10% of the Company’s jurisdictional retail sales in New Mexico is fixed at $0.021 per kWh. The Company and all intervenors entered into the New Mexico Stipulation on the Company’s compliance filing.

 

C. Common Stock

 

Common Stock Repurchase Program

 

In February 2004, the Board of Directors authorized a new stock repurchase program permitting the repurchase of up to 2 million shares of its outstanding common stock. During the second quarter of 2004, the Company repurchased 50,000 shares of common stock. Since the inception of the stock repurchase programs in 1999, the Company has repurchased a total of 15,050,000 shares of common stock at an aggregate cost of $171.8 million, including commissions. The Company may continue making purchases of its stock at open market prices and may engage in private transactions, where appropriate. The repurchased shares will be available for issuance under employee benefit and stock option plans, or may be retired.

 

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(Unaudited)

 

Reconciliation of Basic and Diluted Earnings Per Share

 

The reconciliation of basic and diluted earnings per share before cumulative effect of accounting change is presented below:

 

     Three Months Ended June 30,

     2004

   2003

     Income

   Shares

   Per
Share


   Income

   Shares

   Per
Share


     (In thousands)              (In thousands)          

Basic earnings per share:

                                     

Net Income

   $ 7,773    47,500,257    $ 0.16    $ 4,995    48,659,155    $ 0.10
                

              

Effect of dilutive securities:

                                     

Unvested restricted stock

        17,505                41,707       

Stock options

        448,703                336,811       
    

  
         

  
      

Diluted earnings per share:

                                     

Net Income

   $ 7,773    47,966,465    $ 0.16    $ 4,995    49,037,673    $ 0.10
    

  
  

  

  
  

 

     Six Months Ended June 30,

     2004

   2003

     Income

   Shares

   Per
Share


   Income

   Shares

   Per
Share


     (In thousands)              (In thousands)          

Basic earnings per share:

                                     

Income before cumulative effect of accounting change

   $ 10,760    47,475,778    $ 0.23    $ 7,111    48,981,211    $ 0.15
                

              

Effect of dilutive securities:

                                     

Unvested restricted stock

        20,431                23,826       

Stock options

        437,174                322,149       
    

  
         

  
      

Diluted earnings per share:

                                     

Income before cumulative effect of accounting change

   $ 10,760    47,933,383    $ 0.22    $ 7,111    49,327,186    $ 0.15
    

  
  

  

  
  

 

     Twelve Months Ended June 30,

     2004

   2003

     Income

   Shares

   Per
Share


   Income

   Shares

   Per
Share


     (In thousands)              (In thousands)          

Basic earnings per share:

                                     

Income before cumulative effect of accounting change

   $ 24,265    47,677,134    $ 0.51    $ 17,909    49,335,156    $ 0.36
                

              

Effect of dilutive securities:

                                     

Unvested restricted stock

        50,111                61,880       

Stock options

        396,252                330,173       
    

  
         

  
      

Diluted earnings per share:

                                     

Income before cumulative effect of accounting change

   $ 24,265    48,123,497    $ 0.50    $ 17,909    49,727,209    $ 0.36
    

  
  

  

  
  

 

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(Unaudited)

 

Options excluded from the computation of diluted earnings per share because the exercise price was greater than the average market price for the periods presented are as follows:

 

     Three Months
Ended June 30,


   Six Months
Ended June 30,


   Twelve Months
Ended June 30,


     2004

   2003

   2004

   2003

   2004

   2003

Options excluded

     154,449      966,041      356,597      1,120,580      686,054      1,120,580

Exercise price range

   $ 14.50—$15.99    $ 11.88—$15.99    $ 13.77—$15.99    $ 11.00—$15.99    $ 11.88—$15.99    $ 11.00—$15.99

 

D. Commitments, Contingencies and Uncertainties

 

For a full discussion of commitments and contingencies, see Note I of Notes to Consolidated Financial Statements in the 2003 Form 10-K. In addition, see Note B above and Notes B and C of Notes to Consolidated Financial Statements in the 2003 Form 10-K regarding matters related to regulation and Palo Verde, including decommissioning, spent fuel storage, disposal of low-level radioactive waste, steam generators and liability and insurance matters.

 

Power Contracts

 

In addition to the contracts disclosed in the Company’s 2003 Form 10-K, the Company has entered into a 20-year contract for the purchase of up to 133 MW of capacity and associated energy from Southwestern Public Service Company beginning in 2006. This contract includes a demand charge, energy charge and a transmission charge.

 

Environmental Matters

 

The Company is subject to regulation with respect to air, soil and water quality, solid waste disposal and other environmental matters by federal, state, tribal and local authorities. Those authorities govern current facility operations and have continuing jurisdiction over facility modifications. Failure to comply with these environmental regulatory requirements can result in actions by regulatory agencies or other authorities that might seek to impose on the Company administrative, civil, and/or criminal penalties. In addition, unauthorized releases of pollutants or contaminants into the environment can result in costly cleanup obligations that are subject to enforcement by the regulatory agencies. Environmental regulations can change rapidly and are often difficult to predict. While the Company strives to prepare for and implement changes necessary to comply with changing environmental regulations, substantial expenditures may be required for the Company to comply with such regulations in the future.

 

The Company analyzes the costs of its obligations arising from environmental matters on an ongoing basis, and believes it has made adequate provision in its financial statements to meet such

 

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obligations. As a result of this analysis, the Company has a provision for environmental remediation obligations of approximately $0.8 million as of June 30, 2004, which is related to compliance with federal and state environmental standards. However, unforeseen expenses associated with compliance could have a material adverse effect on the future operations and financial condition of the Company.

 

The Company incurred the following expenditures during the three, six and twelve months ended June 30, 2004 and 2003 to comply with federal environmental statutes (in thousands):

 

     Three Months
Ended June 30,


   Six Months
Ended June 30,


   Twelve Months
Ended June 30,


     2004

   2003

   2004

   2003

   2004

   2003

Clean Air Act

   $ 424    $ 453    $ 634    $ 558    $ 1,136    $ 883

Clean Water Act

     130      235      356      382      623      2,155

 

The Company is not aware of any active investigation of its compliance with environmental requirements by the Environmental Protection Agency, the Texas Commission on Environmental Quality or the New Mexico Environment Department. Furthermore, the Company is not aware of any unresolved, potentially material liability it would face pursuant to the Comprehensive Environmental Response, Compensation and Liability Act of 1980, also known as the Superfund law.

 

Tax Matters

 

The IRS has disputed whether the Company was entitled to deduct certain payments made in 1996 related to Palo Verde and its treatment of a litigation settlement in 1997 related to a terminated merger agreement. The Company has reached a tentative agreement, subject to final IRS approval, to settle these and all other issues relative to its 1996 through 1998 federal income tax returns. The Company expects the IRS will make a final decision regarding the proposed settlement before the end of 2004. Should the proposed settlement be rejected by the IRS, the Company cannot predict the eventual outcome of this matter. Also, the IRS is currently performing an examination of the 1999 through 2002 income tax returns. The Company has established, and periodically reviews and re-evaluates, an estimated contingent tax liability on its consolidated balance sheet to provide for the possibility of adverse outcomes in tax proceedings. Although the ultimate outcome of the settlement or the ongoing examination cannot be predicted with certainty, and while the contingent tax reserve may not in fact be sufficient, the Company believes that the amount of contingent tax reserve recorded as of June 30, 2004 is a reasonable estimate of any additional tax that may be due.

 

Union Matters

 

On October 2 and 3, 2003, employees in the Company’s meter reading and collections areas, comprised of 68 employees, voted in favor of representation by the International Brotherhood of Electrical Workers, Local 960 (“Local 960”). This vote was certified by the National Labor Relations

 

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Board (“NLRB”) on October 14, 2003. In addition, employees in the Company’s facilities services area, comprised of seven employees, voted in favor of representation by Local 960 on October 16, 2003. This vote was certified by the NLRB on October 24, 2003. The Company has begun negotiations with Local 960 on behalf of these employees.

 

On April 2, 2004, Local 960 filed a petition with the NLRB seeking an election to determine union representation for employees in the customer service area. The Company challenged the appropriateness of the employee unit petitioned by Local 960. On June 10, 2004, the NLRB decided the appropriate group eligible to vote consisted of 65 hourly, customer service employees in the Company’s phone center, outlying areas and customer resource unit. The election is scheduled for August 20, 2004.

 

E. Litigation

 

The Company is a party to various legal actions. In many of these matters, the Company has excess casualty liability insurance that covers the various claims, actions and complaints. Based upon a review of these claims and applicable insurance coverage, the Company believes that, except as described below, none of these claims will have a material adverse effect on the financial position, results of operations and cash flows of the Company.

 

On January 16, 2003, the Company was served with a complaint on behalf of a purported class of shareholders alleging violations of the federal securities laws (Roth v. El Paso Electric Company, et al., No. EP-03-CA-0004). The complaint was filed in the El Paso Division of the United States District Court for the Western District of Texas. The suit seeks undisclosed compensatory damages for the class as well as costs and attorneys’ fees. The lead plaintiff, Carpenters Pension Fund of Illinois, filed a consolidated amended complaint on July 2, 2003, alleging, among other things, that the Company and certain of its current and former directors and officers violated securities laws by failing to disclose that some of the Company’s revenues and income were derived from an allegedly unlawful relationship with Enron. The allegations arise out of the FERC investigation of the power markets in the western United States during 2000 and 2001, which the Company previously settled with the FERC Trial Staff and certain intervening parties. On August 15, 2003, the Company and the individual defendants filed a motion to dismiss the complaint for failure to state a claim upon which relief can be granted. On November 26, 2003, the Court denied the motion to dismiss as to the Company and three of the individual defendants and granted the motion to dismiss as to two individual defendants. On April 13, 2004, the Court granted a motion of the Company and the remaining individual defendants requesting permission to file an interlocutory appeal to the U. S. Court of Appeals for the Fifth Circuit regarding certain legal questions relating to the Court’s denial of the motion to dismiss the complaint as to those defendants. On April 27, 2004, the Court entered an order staying the district court proceedings until the Fifth Circuit completed its review. On June 7, 2004, the U. S. Court of Appeals denied the appeal which automatically lifted the stay in the district court. This matter is presently set for trial on March 28, 2005, but such date may be extended. While the Company believes the lawsuit is without merit and intends to defend itself vigorously, the Company is unable to predict the outcome.

 

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On May 21, 2003, the Company was served with a complaint by the Port of Seattle seeking civil damages under the Sherman Act, the Racketeer Influenced and Corrupt Organization Act, and state anti-trust laws, as well as for fraud (Port of Seattle v. Avista Corporation, et al., No. CV03-117OP). The complaint was filed in the United States District Court for the Western District of Washington. The complaint alleges that the Company, indirectly through its dealings with Enron, conspired with the other named defendants to manipulate the California energy market, which had the effect of artificially inflating the price that the Port of Seattle paid for electricity. The Company, together with several other defendants, filed a motion to dismiss. On May 12, 2004, the Court granted the Company’s motion, and the suit was dismissed. The Port of Seattle has filed an appeal of the Court’s decision with the U. S. Court of Appeals for the Ninth Circuit.

 

On May 5, 2004, Wah Chang, a specialty metals manufacturer which operates a plant in Oregon, filed suit against the Company and other defendants in the United States District Court for the District of Oregon. (Wah Chang v. Avista Corporation, et al., No. 04-619AS). The complaint makes substantially the same allegations as were made in Port of Seattle and seeks the same types of damages. In addition, on June 7, 2004, the City of Tacoma filed suit against the Company and other defendants in the United States District Court for the Western District of Washington (City of Tacoma v. American Electric Power Service Corp., et al., C04-5325RBL). This complaint also makes substantially the same allegations as were made in Port of Seattle and seeks civil damages (including treble damages) from the Company and the other defendants for violations of certain antitrust provisions under the Sherman Act. Based on court rulings in Port of Seattle, the Company anticipates that both of these matters will be transferred to the same court that heard and dismissed the Port of Seattle lawsuit. While the Company believes that these matters are without merit and intends to defend itself vigorously, the Company is unable to predict the outcome.

 

On November 3, 2003, TNP filed a complaint against the Company with the FERC, asking the FERC to make a determination that TNP has certain “rollover rights” to network-type transmission service over the Company’s transmission system as a result of a power sales agreement between it and the Company which expired at the end of 2002. TNP asserts that it has such rights under the rollover provisions of FERC Order No. 888. The Company has responded to TNP’s complaint by contesting TNP’s assertion of rollover rights on several grounds. Due to existing transmission constraints, a FERC ruling granting TNP’s complaint could adversely impact the Company’s ability to import lower cost power from Palo Verde and Four Corners to serve its retail customers, which could result in higher rates for the Company’s retail electric customers. A hearing on this matter before an administrative law judge was held on July 19 and 20, 2004, and the Company is awaiting a decision. The Company cannot predict the outcome of this matter or the effect that an adverse ruling by the FERC might have on the Company or its retail customers.

 

On June 29, 2004, the Company filed suit against TNP in the Third Judicial District Court of New Mexico, claiming that TNP acted in bad faith by claiming such transmission rights and seeking to obtain use of more transmission rights than originally allocated to TNP under its original contract with the Company. The Company seeks both actual and exemplary damages from TNP as well as a

 

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declaration that TNP breached its agreements with the Company, acted in bad faith and violated New Mexico law prohibiting such actions.

 

On February 9, 2004, Enron North America Corp. (“ENA”) filed suit against the Company seeking payment of approximately $5.4 million, plus interest and costs, relating to certain natural gas supply contracts (Enron North America Corp. v. El Paso Electric Co., Case No. 01-16034, United States Bankruptcy Court, Southern District of New York). The complaint alleges that ENA entered into two natural gas supply contracts with the Company which automatically terminated as a result of ENA’s bankruptcy. ENA contends that, under the terms of the contracts, the Company owes ENA termination payments because the market price of natural gas at the date of termination was lower than the contract price. While ENA acknowledges that the contracts contain a provision (the “One-Way Payment Provision”) under which the termination payment would be calculated to be zero, ENA seeks a ruling from the court that the One-Way Payment Provision is unenforceable and that the Company should be required to pay termination payments in the amount of approximately $5.4 million, plus interest and costs. The first of these two contracts covers gas to be supplied by ENA during the months of November and December of 2001 (the “2001 Contract”). The Company estimates that the value of the termination payment claimed by ENA under the 2001 Contract is approximately $1.8 million. The second of these two contracts covers gas to be supplied by ENA during the months of January through December of 2002 (the “2002 Contract”). The Company estimates that the value of the termination payment claimed by ENA under the 2002 Contract is approximately $3.6 million. Based upon the Company’s assessment of the probability of an adverse outcome, the Company expensed $1.5 million, pre-tax, in 2003 for this matter. On April 19, 2004, the Bankruptcy Court approved a confidential settlement agreement and mutual release by and between ENA and the Company, resolving all issues in the suit. The Company does not expect any further charge to earnings as a result of this settlement.

 

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F. Employee Benefits

 

Retirement Plans

 

The net periodic benefit cost recognized for the three, six and twelve months ended June 30, 2004 and 2003 is made up of the components listed below as determined using the projected unit credit actuarial cost method (in thousands):

 

    

Three Months

Ended

June 30,


   

Six Months

Ended

June 30,


 
     2004

    2003

    2004

    2003

 

Components of net periodic benefit cost:

                                

Service cost

   $ 1,113     $ 953     $ 2,226     $ 1,906  

Interest cost

     2,522       2,403       5,044       4,806  

Expected return on plan assets

     (1,927 )     (1,884 )     (3,854 )     (3,768 )

Amortization of:

                                

Unrecognized loss

     843       434       1,686       868  

Unrecognized prior service cost

     5       5       10       10  
    


 


 


 


Net periodic benefit cost

   $ 2,556     $ 1,911     $ 5,112     $ 3,822  
    


 


 


 


    

Twelve Months

Ended

June 30,


             
     2004

    2003

             

Components of net periodic benefit cost:

                                

Service cost

   $ 4,132     $ 3,585                  

Interest cost

     9,848       9,368                  

Expected return on plan assets

     (7,622 )     (7,649 )                

Amortization of:

                                

Unrecognized loss

     2,554       868                  

Unrecognized prior service cost

     21       21                  
    


 


               

Net periodic benefit cost

   $ 8,933     $ 6,193                  
    


 


               

 

During the six months ended June 30, 2004, the Company contributed $3.8 million to its retirement plans. By September 15, 2004, the Company anticipates it will contribute, at a minimum, an additional $7.9 million. This additional contribution will increase total contributions to $15.5 million in 2004.

 

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(Unaudited)

 

Other Postretirement Benefits

 

The net periodic benefit cost recognized for the three, six and twelve months ended June 30, 2004 and 2003 is made up of the components listed below (in thousands):

 

    

Three Months
Ended

June 30,


   

Six Months

Ended

June 30,


 
     2004

    2003

    2004

    2003

 

Components of net periodic benefit cost:

                                

Service cost

   $ 1,159     $ 979     $ 2,318     $ 1,958  

Interest cost

     1,756       1,617       3,512       3,234  

Expected return on plan assets

     (315 )     (255 )     (630 )     (510 )

Amortization of unrecognized gain

                        
    


 


 


 


Net periodic benefit cost

   $ 2,600     $ 2,341     $ 5,200     $ 4,682  
    


 


 


 


    

Twelve Months

Ended

June 30,


             
     2004

    2003

             

Components of net periodic benefit cost:

                                

Service cost

   $ 4,275     $ 3,516                  

Interest cost

     6,746       6,080                  

Expected return on plan assets

     (1,140 )     (1,009 )                

Amortization of unrecognized gain

           (396 )                
    


 


               

Net periodic benefit cost

   $ 9,881     $ 8,191                  
    


 


               

 

During the six months ended June 30, 2004, the Company contributed $1.7 million to its other postretirement benefits plan.

 

In December 2003, the Company elected to defer recognition of the potential effect of the Medicare Prescription Drug, Improvement, and Modernization Act of 2003 (the “Act”) until authoritative guidance on the accounting for the federal subsidy is issued. In May 2004, the Financial Accounting Standards Board (“FASB”) issued FASB Staff Position No. 106-2 (“FSP 106-2”) which requires measurement of the accumulated post-retirement benefit obligation and the net periodic post-retirement benefit cost to reflect the effects of the subsidy for interim or annual periods beginning after June 15, 2004. The Company has not yet determined the effects of the Act on its results of operations, financial condition or liquidity.

 

G. Franchises and Significant Customers

 

City of El Paso Franchise

 

The Company’s franchise agreement with the City of El Paso, Texas (“City”) includes an option to acquire all of the non-cash assets of the Company at the end of the franchise on August 1, 2005. To

 

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EL PASO ELECTRIC COMPANY AND SUBSIDIARY

 

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

 

(Unaudited)

 

exercise the option, the City was required to deliver written notice to the Company one year prior to the expiration of the franchise term. The option expired on August 1, 2004 without being exercised by the City.

 

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Report of Independent Registered Public Accounting Firm

 

The Board of Directors and Shareholders

El Paso Electric Company:

 

We have reviewed the condensed consolidated balance sheet of El Paso Electric Company and subsidiary as of June 30, 2004, the related condensed consolidated statements of operations and comprehensive operations for the three-month, six-month, and twelve-month periods ended June 30, 2004 and 2003, and the related condensed consolidated statements of cash flows for the six-month periods ended June 30, 2004 and 2003. These condensed consolidated financial statements are the responsibility of the Company’s management.

 

We conducted our reviews in accordance with standards of the Public Company Accounting Oversight Board (United States). A review of interim financial information consists principally of applying analytical procedures and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with the standards of the Public Company Accounting Oversight Board (United States), the objective of which is the expression of an opinion regarding the financial statements taken as a whole. Accordingly, we do not express such an opinion.

 

Based on our reviews, we are not aware of any material modifications that should be made to the condensed consolidated financial statements referred to above for them to be in conformity with U.S. generally accepted accounting principles.

 

We have previously audited, in accordance with standards of the Public Company Accounting Oversight Board (United States), the consolidated balance sheet of El Paso Electric Company and subsidiary as of December 31, 2003, and the related consolidated statements of operations, comprehensive operations, changes in common stock equity, and cash flows for the year then ended (not presented herein); and in our report dated March 10, 2004, we expressed an unqualified opinion on those consolidated financial statements. Our report referred to a change in the Company’s method of accounting for asset retirement obligations in 2003. In our opinion, the information set forth in the accompanying condensed consolidated balance sheet as of December 31, 2003 is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived.

 

KPMG LLP

 

El Paso, Texas

August 5, 2004

 

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations

 

The information contained in this Item 2 updates, and should be read in conjunction with, the information set forth in Part II, Item 7 of the Company’s 2003 Form 10-K.

 

Statements in this document, other than statements of historical information, are forward-looking statements that are made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Such forward-looking statements, as well as other oral and written forward-looking statements made by or on behalf of the Company from time to time, including statements contained in the Company’s filings with the Securities and Exchange Commission and its reports to shareholders, involve known and unknown risks and other factors which may cause the Company’s actual results in future periods to differ materially from those expressed in any forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to: (i) increased prices for fuel and purchased power and determinations by regulators that may adversely affect the Company’s ability to recover incurred fuel costs in rates; (ii) fluctuations in economy sales and margins due to uncertainty in the economy power market; (iii) unanticipated increased costs associated with scheduled and unscheduled outages; (iv) the cost of replacing steam generators for Palo Verde Units 1 and 3 and other costs at Palo Verde; (v) the costs of legal defense and possible judgments which may accrue as the result of litigation arising out of the FERC investigation or any other regulatory proceeding; (vi) deregulation of the electric utility industry; and (vii) other factors discussed below under the headings “Summary of Critical Accounting Policies and Estimates,” “Overview” and “Liquidity and Capital Resources.” The Company’s filings are available from the Securities and Exchange Commission or may be obtained through the Company’s website, www.epelectric.com. Any such forward-looking statement is qualified by reference to these risks and factors. The Company cautions that these risks and factors are not exclusive. The Company does not undertake to update any forward-looking statement that may be made from time to time by or on behalf of the Company except as required by law.

 

Summary of Critical Accounting Policies and Estimates

 

The preparation of the Company’s financial statements requires management to make estimates and assumptions that affect the amounts reported in the consolidated financial statements and related notes for the periods presented and actual results could differ in future periods from those estimates. In addition to the discussion on reapplication of SFAS No. 71, “Accounting for the Effects of Certain Types of Regulation,” presented below, critical accounting policies and estimates, which are both important to the portrayal of the Company’s financial condition and results of operations and which require complex, subjective judgments are more fully described in the “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in the Company’s 2003 Form 10-K.

 

SFAS No. 71

 

Regulated electric utilities typically prepare their financial statements in accordance with SFAS No. 71. Under this accounting standard, certain recoverable costs, with cost recovery being provided either before or after the costs are incurred, are shown as either assets or liabilities on a utility’s balance sheet, if the regulator provides assurance that these costs will be charged to and collected from its customers (or has already permitted such cost recovery). The resulting regulatory assets and or liabilities

 

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are amortized in subsequent periods based upon their respective amortization periods in a utility’s cost of service.

 

Beginning in 1991, the Company discontinued the application of SFAS No. 71 to its financial statements. This decision was based on the Company’s determination that its rates were no longer designed to recover its costs of providing service to customers. Upon emerging from bankruptcy in 1996, the Company again concluded that it did not meet the criteria for applying SFAS No. 71 because of the 10-year rate freeze in Texas and its ongoing intention not to seek changes in its New Mexico rates, which had been established in 1990.

 

The Company regularly analyzes whether it meets the criteria for reapplication of SFAS No. 71 to some or all of its business. Recently, the Company settled a cost of service-based rate case in New Mexico. In August 2005, the Texas Freeze Period will terminate and at some point the Company’s generation business in Texas could be deregulated. These or other factors may lead the Company to conclude that the financial results for some or all of its business should in the future be prepared in accordance with SFAS No. 71. This change would generally require that certain costs (e.g. OPEB transition obligations or accumulated deferred investment tax credits) be recorded as regulatory assets or regulatory liabilities, and that a corresponding charge or credit to income be recorded during the period. There would be no change in the Company’s present method of accounting for fuel expense under-recoveries and over-recoveries which are recorded as assets or liabilities until collected or repaid in accordance with generally accepted accounting principles, as required by statutes in both Texas and New Mexico.

 

The Company expects to complete its current evaluation during the third quarter of 2004.

 

Overview

 

El Paso Electric Company is an investor owned electric utility that serves retail customers in west Texas and southern New Mexico and wholesale customers in Texas. The Company also periodically sells power to the CFE. The Company owns or has substantial ownership interests in six electrical generating facilities providing it with a total capacity of approximately 1,500 MW. The Company’s energy sources consist of nuclear fuel, natural gas, coal, wind powered resources and purchased power. The Company owns or has significant ownership interests in four major 345 kV transmission lines and three 500 kV transmission lines utilized to transfer power from Palo Verde and Four Corners, and owns the transmission and distribution network within its retail service territory. The Company is subject to regulation by the Texas and New Mexico Commissions and, with respect to wholesale power sales, transmission of electric power and the issuance of securities, the FERC.

 

The Company faces a number of risks and challenges that could negatively impact its operations and financial results. The most significant of these risks and challenges are the deregulation of the electric utility industry and the possibility of increased costs especially from Palo Verde.

 

The electric utility industry in general and the Company in particular are facing significant challenges and increased competition as a result of changes in federal provisions relating to third-party transmission services and independent power production, as well as changes in state laws and regulatory provisions relating to wholesale and retail service. In 1999, both Texas and New Mexico passed industry deregulation legislation requiring the Company to separate its transmission and distribution

 

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functions, which would remain regulated, from its power generation and energy services businesses, which would operate in a competitive market in the future. New Mexico repealed the New Mexico Restructuring Act in April 2003, and the Company’s operations in New Mexico will remain fully regulated. In Texas, the Company’s service territory has not yet been deregulated, but the Company is preparing for retail competition. If the Company does not enter retail competition for generating services at the end of the Freeze Period, the Company’s generating services will continue to be regulated by the Texas Commission. The Texas Commission opened a project (Project No. 28971) to evaluate the readiness of the Company’s service area in Texas for retail competition. In this project, the Texas Commission may specify in advance the factors that are important in deciding when and how to open the Company’s service area in Texas to customer choice. The Texas Commission has published and taken comments from interested parties on a proposed rule. The proposed rule sets forth a process and sequence of events for the introduction of retail competition in the Company’s service territory. The proposed sequence of events is based upon completion of the specific items in each stage before the next stage is initiated. Based on the Texas Commission’s proposed rule, the first event that must occur before the introduction of competition in the Company’s service territory is the creation of an operating regional transmission organization. If the proposed rule is adopted in its present form, retail competition in the El Paso area would not begin for several years. The Texas Commission is expected to issue its final rule before the end of 2004. There is substantial uncertainty about both the regulatory framework and market conditions that will exist if and when retail competition is implemented in the Company’s Texas service territory and the Company may incur substantial preparatory, restructuring and other costs that may not ultimately be recoverable. There can be no assurance that deregulation would not adversely affect the future operations, cash flows and financial condition of the Company.

 

The changing regulatory environment and the potential for unregulated power production have created a substantial risk that the Company will lose important customers. The Company’s wholesale and large retail customers already have, in varying degrees, alternate sources of economical power, including co-generation of electric power. If the Company loses a significant portion of its retail customer base, the Company may not be able to replace such revenues through either the addition of new customers, an increase in rates to remaining customers, or sales in the economy market.

 

Another risk to the Company is potential increased costs, including the risk of additional or unanticipated costs at Palo Verde resulting from (i) increases in operation and maintenance expenses; (ii) the replacement of steam generators in Palo Verde Units 1 and 3; (iii) an extended outage of any of the Palo Verde units; (iv) increases in estimates of decommissioning costs; (v) the storage of radioactive waste, including spent nuclear fuel; (vi) insolvency of other Palo Verde Participants; and (vii) compliance with the various requirements and regulations governing commercial nuclear generating stations. At the same time, the Company’s retail base rates in Texas are effectively capped through a rate freeze ending in August 2005. As a result, the Company cannot raise its base rates in Texas in the event of increases in non-fuel costs or loss of revenue. Additionally, upon initiation of competition, there may be competitive pressure on the Company’s power generation rates which could reduce its profitability. The Company cannot assure that its revenues will be sufficient to recover any increased costs, including any increased costs in connection with Palo Verde or other operations, whether as a result of inflation, changes in tax laws or regulatory requirements, or other causes.

 

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Liquidity and Capital Resources

 

The Company’s principal liquidity requirements in the near-term are expected to consist of interest payments on the Company’s indebtedness, operating and capital expenditures related to the Company’s generating facilities and transmission and distribution systems, income and other taxes, and reorganization costs related to deregulation in Texas, if and when deregulation occurs. The Company expects that cash flows from operations will be sufficient for such purposes. As of June 30, 2004, the Company had approximately $26.9 million in cash and cash equivalents, a decrease of $7.5 million from the balance of $34.4 million on December 31, 2003.

 

In addition to the contractual obligations disclosed in the Company’s 2003 Form 10-K, in July 2004 the Company entered into a 20-year power contract beginning in 2006. The contractual obligation related to this contract will be $11.3 million for 2006, $23.2 million for 2007 and 2008 and $230.3 million for 2009 and later.

 

Pollution control bonds of $193.1 million are subject to remarketing in 2005, and first mortgage bonds of $175.8 million are scheduled to mature in 2006. The Company expects that these obligations and the $100 million revolving credit facility, which matures in January 2005 (against which approximately $41.9 million had been drawn for nuclear fuel purchases as of June 30, 2004) will be refinanced through the capital and credit markets. Additionally, the Company has $194.1 million of first mortgage bonds which become callable in 2006. The Company’s ability to access capital and credit markets may be adversely affected by uncertainties related to operating in a competitive energy market, tight credit markets and debt rating agency actions.

 

Long-term capital requirements of the Company will consist primarily of construction of electric utility plant and the payment of interest on and retirement and refinancing of debt. Utility construction expenditures will consist primarily of expanding and updating the transmission and distribution systems, possible addition of new generation, and the cost of capital improvements and replacements at Palo Verde and other generating facilities, including the replacement of steam generators in Palo Verde Units 1 and 3.

 

During the twelve months ended June 30, 2004 and 2003, the Company utilized $2.5 million and $70.9 million, respectively, of federal tax loss carryforwards. The Company anticipates that existing federal tax loss carryforwards will be fully utilized in 2004, should the IRS settlement for the tax years 1996 through 1998 be approved by the IRS, and that the Company’s cash flow requirements for income taxes are expected to increase over that required in recent years.

 

The Company is continually evaluating its funding requirements related to its retirement plans, other postretirement benefit plans, and decommissioning trust funds. By September 15, 2004, the Company anticipates it will contribute, at a minimum, an additional $7.9 million to its pension plan. The Company contributed an additional $3.2 million to one of its retirement plans in September 2003. The Company also contributed an additional $4.7 million to the decommissioning trust funds in January 2003 in order to meet its funding requirement as of December 31, 2002.

 

Since inception of its deleveraging program in 1996, the Company has repurchased or retired with internally generated cash $575.9 million of first mortgage bonds. First Mortgage Bonds totaling $25.4 million were repurchased in the six month period ended June 30, 2004. Common stock equity as a

 

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percentage of capitalization, including current portion of long-term debt and financing obligations, was 46% as of June 30, 2004.

 

Although the Company is currently at industry averages, the degree to which the Company is leveraged could have important consequences for the Company’s liquidity, including (i) limiting the Company’s ability to obtain additional financing for working capital, capital expenditures, acquisitions, general corporate or other purposes in the future; and (ii) placing the Company at a competitive disadvantage by limiting its financial flexibility to respond to the demands of the competitive market and making it more vulnerable to adverse economic or business changes.

 

Since the inception of the stock repurchase programs in 1999, the Company has repurchased 15.1 million shares in total at an aggregate cost of $171.8 million, including commissions. In February 2004, the Board of Directors authorized a new stock repurchase program permitting the repurchase of up to 2 million shares of its outstanding common stock. During the second quarter of 2004, the Company repurchased approximately 50,000 shares of common stock in the open market. The Company may continue making purchases of its stock at open market prices and may engage in private transactions, where appropriate. The repurchased shares will be available for issuance under employee benefit and stock option plans, or may be retired.

 

Historical Results of Operations

 

    

Three Months

Ended June 30,


  

Six Months

Ended June 30,


     2004

   2003

   2004

   2003

Income before cumulative effect of accounting change (in thousands)

   $ 7,773    $ 4,995    $ 10,760    $ 7,111

Diluted earnings per share before cumulative effect of accounting change

     0.16      0.10      0.22      0.15

 

     Twelve Months
Ended June 30,


     2004

   2003

     Actual

   Actual

   Pro forma

Income before cumulative effect of accounting change (in thousands)

   $ 24,265    $ 17,909    $ 20,221

Diluted earnings per share before cumulative effect of accounting change

     0.50      0.36      0.41

 

Income before the cumulative effect of accounting change for the three months ended June 30, 2004 increased $2.8 million, or $0.06 diluted earnings per share, compared to the results for the same period a year ago. This after-tax increase resulted primarily from decreased non-Palo Verde maintenance expense of $2.4 million, increased retail sales of $1.4 million and decreased Palo Verde operation and maintenance expense of $0.7 million. These increases were partially offset by the loss on

 

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extinguishment of debt of $1.1 million, after-tax and increased depreciation and amortization expense of $0.8 million, after-tax.

 

Income before the cumulative effect of accounting change for the six months ended June 30, 2004 increased $3.6 million, or $0.07 diluted earnings per share, compared to the results for the same period a year ago. This after-tax increase resulted primarily from decreased non-Palo Verde maintenance expense of $5.8 million and increased retail sales of $4.0 million. These increases were partially offset by the following items, which are all presented on an after-tax basis (i) an increase in the loss on extinguishment of debt of $2.3 million; (ii) increased depreciation and amortization expense of $1.9 million; (iii) decreased economy sales and margins of $0.8 million; and (iv) increased pension and benefits expense of $0.8 million.

 

Income before the cumulative effect of accounting change for the twelve months ended June 30, 2004 increased $4.0 million or $0.09 diluted earnings per share, compared to the pro forma results for the same period a year ago. The pro forma net income and earnings per share amounts shown above assume SFAS No. 143 had been applied on a retroactive basis. This after-tax increase was primarily due to the following items, which are all presented on an after-tax basis (i) the 2002 accrual for the FERC settlements of $9.5 million; (ii) decreased non-Palo Verde maintenance expense of $9.1 million; and (iii) increased retail sales of $8.9 million. These increases were partially offset by (i) the impairment loss on the CIS project of $10.7 million; (ii) decreased wholesale sales revenue of $6.4 million primarily related to the expiration of two long-term contracts; (iii) the Texas fuel disallowance of $2.7 million; (iv) increased pension and benefits expenses of $2.9 million; and (v) an increase in the loss on extinguishment of debt of $2.3 million.

 

Operating revenues net of energy expenses increased $1.9 million and $3.5 million for the three and six months ended June 30, 2004, respectively, compared to the same periods last year, primarily due to increased retail sales of $2.3 million and $6.6 million, respectively. The increase for the six month period ended June 30, 2004 was partially offset by (i) decreased sales and/or margins on economy sales of $1.3 million; (ii) $0.6 million of various unreconcilable fuel expense items; and (iii) 2003 CFE margins of $0.4 million with no comparable activity in 2004.

 

Operating revenues net of energy expenses decreased $3.4 million for the twelve months ended June 30, 2004 compared to the same period last year, primarily due to (i) decreased wholesale sales revenues of $10.5 million primarily related to the expiration of two long-term contracts; (ii) the Texas fuel disallowance of $4.5 million; (iii) a $1.8 million decrease in revenue from the energy service operation; and (iv) the $1.6 million expense which related to the settlement agreement with ENA. This decrease was partially offset by an increase in retail sales of $14.6 million.

 

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Comparisons of kWh sales and operating revenues are shown below (in thousands):

 

               Increase (Decrease)

 

Quarter Ended June 30:


   2004

   2003

   Amount

    Percent

 

kWh sales:

                            

Retail:

                            

Residential

     468,486      447,248      21,238     4.7 %

Commercial and industrial, small

     556,515      535,141      21,374     4.0  

Commercial and industrial, large

     315,445      301,785      13,660     4.5  

Sales to public authorities

     323,768      315,943      7,825     2.5  
    

  

  


     

Total retail sales

     1,664,214      1,600,117      64,097     4.0  
    

  

  


     

Wholesale:

                            

Sales for resale

     13,486      29,313      (15,827 )   (54.0 )(1)

Economy sales

     431,354      417,896      13,458     3.2  
    

  

  


     

Total wholesale sales

     444,840      447,209      (2,369 )   (0.5 )
    

  

  


     

Total kWh sales

     2,109,054      2,047,326      61,728     3.0  
    

  

  


     

Operating revenues:

                            

Base revenues:

                            

Retail:

                            

Residential

   $ 41,981    $ 40,437    $ 1,544     3.8 %

Commercial and industrial, small

     43,346      42,418      928     2.2  

Commercial and industrial, large

     11,013      11,023      (10 )   (0.1 )

Sales to public authorities

     19,045      19,174      (129 )   (0.7 )
    

  

  


     

Total retail base revenues

     115,385      113,052      2,333     2.1  

Wholesale:

                            

Sales for resale

     520      1,557      (1,037 )   (66.6 )(1)
    

  

  


     

Total base revenues

     115,905      114,609      1,296     1.1  

Fuel revenues

     45,070      30,470      14,600     47.9 (2)

Economy sales

     18,527      15,639      2,888     18.5 (3)

Other

     2,704      1,780      924     51.9 (4)(5)
    

  

  


     

Total operating revenues

   $ 182,206    $ 162,498    $ 19,708     12.1  
    

  

  


     

 

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               Increase (Decrease)

 

Six Months Ended June 30:


   2004

   2003

   Amount

    Percent

 

kWh sales:

                            

Retail:

                            

Residential

     936,803      878,450      58,353     6.6 %

Commercial and industrial, small

     1,011,363      972,704      38,659     4.0  

Commercial and industrial, large

     618,835      566,526      52,309     9.2  

Sales to public authorities

     602,672      573,448      29,224     5.1  
    

  

  


     

Total retail sales

     3,169,673      2,991,128      178,545     6.0  
    

  

  


     

Wholesale:

                            

Sales for resale

     22,753      39,206      (16,453 )   (42.0 )(1)

Economy sales

     917,974      1,033,584      (115,610 )   (11.2 )(6)
    

  

  


     

Total wholesale sales

     940,727      1,072,790      (132,063 )   (12.3 )
    

  

  


     

Total kWh sales

     4,110,400      4,063,918      46,482     1.1  
    

  

  


     

Operating revenues:

                            

Base revenues:

                            

Retail:

                            

Residential

   $ 82,152    $ 77,819    $ 4,333     5.6 %

Commercial and industrial, small

     79,447      78,123      1,324     1.7  

Commercial and industrial, large

     21,303      20,910      393     1.9  

Sales to public authorities

     35,603      35,063      540     1.5  
    

  

  


     

Total retail base revenues

     218,505      211,915      6,590     3.1  

Wholesale:

                            

Sales for resale

     912      1,947      (1,035 )   (53.2 )(1)
    

  

  


     

Total base revenues

     219,417      213,862      5,555     2.6  

Fuel revenues

     76,344      51,967      24,377     46.9 (2)

Economy sales

     37,491      40,670      (3,179 )   (7.8 )(6)

Other

     4,806      3,485      1,321     37.9 (4)(5)
    

  

  


     

Total operating revenues

   $ 338,058    $ 309,984    $ 28,074     9.1  
    

  

  


     

 

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               Increase (Decrease)

 

Twelve Months Ended June 30:


   2004

   2003

   Amount

    Percent

 

kWh sales:

                            

Retail:

                            

Residential

     1,990,524      1,878,726      111,798     6.0 %

Commercial and industrial, small

     2,135,519      2,063,254      72,265     3.5  

Commercial and industrial, large

     1,249,374      1,158,565      90,809     7.8  

Sales to public authorities

     1,253,573      1,203,875      49,698     4.1  
    

  

  


     

Total retail sales

     6,628,990      6,304,420      324,570     5.1  
    

  

  


     

Wholesale:

                            

Sales for resale

     51,301      419,427      (368,126 )   (87.8 )(7)

Economy sales

     1,805,272      1,904,830      (99,558 )   (5.2 )
    

  

  


     

Total wholesale sales

     1,856,573      2,324,257      (467,684 )   (20.1 )
    

  

  


     

Total kWh sales

     8,485,563      8,628,677      (143,114 )   (1.7 )
    

  

  


     

Operating revenues:

                            

Base revenues:

                            

Retail:

                            

Residential

   $ 175,792    $ 166,970    $ 8,822     5.3 %

Commercial and industrial, small

     166,758      163,456      3,302     2.0  

Commercial and industrial, large

     43,687      43,304      383     0.9  

Sales to public authorities

     73,676      71,577      2,099     2.9  
    

  

  


     

Total retail base revenues

     459,913      445,307      14,606     3.3  

Wholesale:

                            

Sales for resale

     2,188      13,501      (11,313 )   (83.8 )(7)
    

  

  


     

Total base revenues

     462,101      458,808      3,293     0.7  

Fuel revenues

     147,138      134,022      13,116     9.8  

Economy sales

     73,357      68,343      5,014     7.3  

Other

     9,840      8,677      1,163     13.4 (4)(8)
    

  

  


     

Total operating revenues

   $ 692,436    $ 669,850    $ 22,586     3.4  
    

  

  


     

(1) Primarily due to a 2003 CFE wholesale power contract with no comparable contract in 2004.
(2) Primarily due to an increase in recoverable fuel expense as a result of an increase in the price and volume of natural gas burned and an increase in purchased power costs.
(3) Primarily due to higher prices in the economy market.
(4) Represents revenues with no related kWh sales.
(5) Primarily due to increased transmission revenues.
(6) Primarily due to decreased available power as a result of outages at Palo Verde and increased retail sales.
(7) Primarily due to the expiration of a wholesale power contract with TNP on December 31, 2002 and a 2003 CFE wholesale power contract with no comparable contract in 2004.
(8) Primarily due to increased transmission revenues partially offset by decreased revenues from the energy service operation.

 

Other operations expense decreased $1.6 million for the three months ended June 30, 2004 compared to the same period last year primarily due to (i) decreased Palo Verde expense of $0.7 million;

 

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(ii) decreased customer accounts expense of $0.4 million; and (iii) decreased legal and consulting fees of $0.4 million.

 

Other operations expense increased $0.3 million for the six months ended June 30, 2004 compared to the same period last year primarily due to (i) increased pension and benefits expense of $1.3 million resulting from plan asset performance and decreasing discount rates; and (ii) increased legal and consulting fees of $0.8 million primarily related to implementing Sarbanes-Oxley Section 404. These increases were partially offset by (i) decreased regulatory expense of $0.8 million; (ii) decreased customer accounts expense of $0.5 million; and (iii) decreased Palo Verde expense of $0.3 million.

 

Other operations expense increased $3.3 million for the twelve months ended June 30, 2004 compared to the same period last year primarily due to (i) increased pension and benefits expense of $4.7 million resulting from plan asset performance and decreasing discount rates; (ii) increased consulting and legal fees of $2.6 million; (iii) increased accretion expense of $2.6 million related to the implementation of SFAS No. 143; and (iv) increased insurance related expenses of $1.8 million. These increases were partially offset by (i) decreased energy services operations expense of $4.7 million primarily due to a warranty reserve recorded in the third quarter of 2002 and the cessation of additional marketing activities by the energy service operation in 2002; and (ii) decreased regulatory expense of $2.9 million.

 

The FERC settlements relate to the settlements with the FERC Trial Staff and principal California parties pursuant to which the Company agreed to refund $15.5 million of revenues it earned on wholesale power transactions in 2000 and 2001. These settlements were recorded in December 2002.

 

The Company abandoned a CIS project and recognized an asset impairment loss of $17.6 million in September 2003. The Company is now analyzing various options to meet its current and projected CIS needs.

 

Maintenance expense decreased $5.0 million, $10.8 million and $18.9 million, respectively, for the three, six and twelve months ended June 30, 2004 compared to the same periods last year primarily due to (i) reduced maintenance outages at non-Palo Verde generating stations of $3.9 million, $10.0 million and $15.0 million, respectively; and (ii) the timing of refueling and maintenance outages at Palo Verde of $0.5 million, $0.4 million and $2.3 million, respectively.

 

Depreciation and amortization expense increased $1.4 million, $3.1 million and $2.6 million for the three, six and twelve months ended June 30, 2004, respectively, compared to the same periods last year. The increases for the three, six and twelve month periods were primarily due to (i) an increase in other depreciable plant balances resulting in increased depreciation of $0.7 million, $1.6 million, and $1.1 million, respectively; (ii) depreciation of the new Palo Verde Unit 2 steam generators of $0.5 million, $1.0 million, and $1.0 million, respectively; and (iii) the implementation of new depreciation rates based on an updated depreciation study resulting in an increase of $0.2 million, $0.5 million, and $0.5 million, respectively.

 

Taxes other than income taxes remained relatively unchanged for the three, six and twelve months ended June 30, 2004 compared to the same periods last year.

 

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Other income (deductions) decreased $2.3 million for the three months ended June 30, 2004 compared to the same period last year primarily due to losses on extinguishments of debt recorded in 2004 with no comparable amount in the prior period. Other income (deductions) decreased $4.4 million for the six months ended June 30, 2004 compared to the same period last year primarily due to (i) losses on extinguishments of debt of $3.8 million; (ii) $1.0 million related to an adjustment of interest income associated with the resolution of the Texas fuel reconciliation in PUC Docket No. 26194; and (iii) $0.4 million related to certain tax refunds received in 2003 with no comparable amount in the current period. These decreases were partially offset by an increase of $0.6 million on investment income related to the decommissioning trust funds. Other income (deductions) decreased $1.2 million for the twelve months ended June 30, 2004 compared to the same period last year due to (i) losses on extinguishments of debt of $3.8 million; and (ii) $1.0 million related to an adjustment of interest income associated with the resolution of the Texas fuel reconciliation in PUC Docket No. 26194. These decreases were partially offset by (i) an increase of $2.2 million on investment income related to the decommissioning trust funds; and (ii) $0.3 million related to certain sales tax refunds.

 

Interest charges (credits) increased $0.1 million and $0.3 million, respectively, for the three and six months ended June 30, 2004 compared to the same period last year primarily due to reduced capitalized interest of $0.5 million and $1.0 million for the three and six month periods, respectively, as a result of transferring Palo Verde Unit 2 steam generators to plant in service. These increases were partially offset by decreased interest expense of $0.4 million and $0.8 million for the three and six month periods, respectively, due to a reduction of outstanding debt as a result of open market purchases of the Company’s first mortgage bonds. Interest charges (credits) decreased $5.7 million for the twelve months ended June 30, 2004 compared to the same period last year primarily due to (i) a $4.1 million decrease resulting from the adoption of SFAS No. 143; and (ii) a $2.4 million decrease resulting from a reduction of outstanding debt as a result of open market purchases of the Company’s first mortgage bonds.

 

Income tax expense, excluding the tax effect of a cumulative effect of accounting change, increased $2.0 million, $2.3 million and $6.0 million for the three, six and twelve months ended June 30, 2004, respectively, compared to the same periods last year primarily due to changes in pretax income and certain permanent differences and adjustments.

 

Item 3. Quantitative and Qualitative Disclosures About Market Risk

 

The Company is exposed to market risk due to changes in interest rates, equity prices and commodity prices. See the Company’s 2003 Form 10-K, Item 7A, “Quantitative and Qualitative Disclosures About Market Risk,” for a complete discussion of the market risks faced by the Company and the Company’s market risk sensitive assets and liabilities. As of June 30, 2004, there have been no material changes in the market risks faced by the Company or the fair values of assets and liabilities disclosed in Item 7A, “Quantitative and Qualitative Disclosures About Market Risk,” in the Company’s 2003 Form 10-K.

 

Item 4. Controls and Procedures

 

Evaluation of disclosure controls and procedures. The Company’s chief executive officer and chief financial officer, after evaluating the effectiveness of the Company’s “disclosure controls and procedures” (as defined in the Securities Exchange Act of 1934 Rules 13a-15(e) and 15d-15(e)) as of June 30, 2004, (the “Evaluation Date”), have concluded that as of the Evaluation Date, the Company’s

 

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disclosure controls and procedures (as required by paragraph (b) of the Securities Exchange Act of 1934 Rules 13a-15 or 15d-15) were adequate and designed to ensure that material information relating to the Company and the Company’s consolidated subsidiary would be made known to them by others within those entities.

 

Changes in internal control over financial reporting. There were no changes in the Company’s internal control over financial reporting in connection with the evaluation required by paragraph (d) of the Securities Exchange Act of 1934 Rules 13a-15 or 15d-15, that occurred during the quarter ended June 30, 2004, that has materially affected, or is reasonably likely to materially affect, the Company’s internal control over financial reporting.

 

PART II. OTHER INFORMATION

 

Item 1. Legal Proceedings

 

The Company hereby incorporates by reference the information set forth in Part I of this report under Notes B and E of Notes to Consolidated Financial Statements.

 

Item 2. Changes in Securities, Use of Proceeds and Issuer Purchases of Equity Securities

 

Period


  

Total Number

of Shares

Purchased


  

Average Price
Paid per Share
(Including

Commissions)


  

Total Number of
Shares Purchased
as Part of a
Publicly
Announced

Program


  

Maximum
Number of
Shares that May
Yet Be Purchased
Under the Plans

or Programs (a)


April 1 to April 30, 2004

   0    $    0    2,000,000

May 1 to May 31, 2004

   0         0    2,000,000

June 1 to June 30, 2004

   50,000      14.91    50,000    1,950,000

 

(a) In February 2004, the Company’s Board of Directors authorized a new stock repurchase program permitting the repurchase of up to 2 million shares of its outstanding common stock. No common stock was repurchased during the first quarter of 2004.

 

Item 4. Submission of Matters to a Vote of Security Holders

 

The annual meeting of shareholders of the Company was held on May 5, 2004. The total number of common shares outstanding was 47,588,360, of which 41,849,533 were represented in person or by

 

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proxy. The following directors were elected to hold office for a three-year term expiring at the annual meeting of shareholders of the Company to be held in 2007:

 

Director


 

Votes For


 

Votes Withheld


J. Robert Brown

  41,509,280   340,253

James W. Cicconi

  41,302,291   547,242

George W. Edwards, Jr.

  41,699,897   149,636

Patricia Z. Holland-Branch

  41,701,904   147,629

 

In addition to the individuals set forth above, the following individuals continued as directors following the meeting: Ramiro Guzman, James W. Harris, Gary R. Hedrick, Kenneth R. Heitz, Michael K. Parks, Eric B. Siegel, Stephen N. Wertheimer and Charles A. Yamarone.

 

Item 6. Exhibits and Reports on Form 8-K

 

(a) Exhibits: See Index to Exhibits incorporated herein by reference.

 

(b) Reports on Form 8-K:

 

Date of Reports


 

Item Numbers


 

Financial Statements Required to be Filed


July 27, 2004

  7 and 12   None

 

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SIGNATURES

 

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

 

        EL PASO ELECTRIC COMPANY
By:   /S/    TERRY BASSHAM        
   

Terry Bassham

Executive Vice President,
Chief Financial and
Administrative Officer
(Duly Authorized Officer and
Principal Financial Officer)

 

Dated: August 9, 2004

 

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EL PASO ELECTRIC COMPANY

 

INDEX TO EXHIBITS

 

Exhibit

Number


  

Exhibit


†10.01    Form of Directors’ Restricted Stock Award Agreement between the Company and certain directors of the Company. (Identical in all material respects to Exhibit 10.07 to the Company’s Quarterly Report on Form 10-Q for the quarter ended June 30, 1999)
††10.02    Form of Directors’ Stock Option Agreement between the Company and certain directors of the Company. (Identical in all material respects to Exhibit 99.17 to the Company’s Annual Report on Form 10-K for the year ended December 31, 1997)
15    Letter re Unaudited Interim Financial Information
31.01    Rule 13a-14(a)/15d-14(a) Certifications
32.01    Section 1350 Certifications
   In lieu of non-employee director cash compensation, three agreements, dated as of April 1, 2004, substantially identical in all material respects to this Exhibit, have been entered into with Kenneth R. Heitz; Patricia Z. Holland-Branch; and Charles A. Yamarone; directors of the Company.
     Eleven agreements, dated as of May 5, 2004, substantially identical in all material respects to this Exhibit, were entered into with George W. Edwards, Jr.; Ramiro Guzman; James W. Harris; Kenneth R. Heitz; James W. Cicconi; Patricia Z. Holland-Branch; Michael K. Parks; Eric B. Siegel; Stephen N. Wertheimer; Charles A. Yamarone; and J. Robert Brown; directors of the Company.
††    In lieu of non-employee director cash compensation, one agreement, dated as of April 1, 2004, substantially identical in all material respects to this Exhibit, has been entered into with Wilson K. Cadman; director of the Company.

 

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