-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, VbnlEl4eoEZMDrYayJrCT1JQVb712KDUJJjAYIJupxv96neU9ZcVlusPi8e/zx4U ErvIqmxgGkM6bGffBO5VKA== 0001004858-99-000091.txt : 19991117 0001004858-99-000091.hdr.sgml : 19991117 ACCESSION NUMBER: 0001004858-99-000091 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 4 CONFORMED PERIOD OF REPORT: 19990930 FILED AS OF DATE: 19991115 FILER: COMPANY DATA: COMPANY CONFORMED NAME: NEW CENTURY ENERGIES INC CENTRAL INDEX KEY: 0001004858 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC & OTHER SERVICES COMBINED [4931] IRS NUMBER: 841334327 STATE OF INCORPORATION: DE FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: SEC FILE NUMBER: 001-12927 FILM NUMBER: 99754450 BUSINESS ADDRESS: STREET 1: 1225 17TH ST CITY: DENVER STATE: CO ZIP: 80202 BUSINESS PHONE: 3035717511 MAIL ADDRESS: STREET 1: 1225 17TH ST CITY: DENVER STATE: CO ZIP: 80202 FILER: COMPANY DATA: COMPANY CONFORMED NAME: PUBLIC SERVICE CO OF COLORADO CENTRAL INDEX KEY: 0000081018 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC & OTHER SERVICES COMBINED [4931] IRS NUMBER: 840296600 STATE OF INCORPORATION: CO FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: SEC FILE NUMBER: 001-03280 FILM NUMBER: 99754451 BUSINESS ADDRESS: STREET 1: 1225 17TH ST STE 900 CITY: DENVER STATE: CO ZIP: 80202 BUSINESS PHONE: 3035717511 MAIL ADDRESS: STREET 1: P O BOX 840 STE 300 CITY: DENVER STATE: CO ZIP: 80201 FILER: COMPANY DATA: COMPANY CONFORMED NAME: SOUTHWESTERN PUBLIC SERVICE CO CENTRAL INDEX KEY: 0000092521 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC SERVICES [4911] IRS NUMBER: 750575400 STATE OF INCORPORATION: NM FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: SEC FILE NUMBER: 001-03789 FILM NUMBER: 99754452 BUSINESS ADDRESS: STREET 1: SPS TOWER STREET 2: TYLER AT SIXTH ST CITY: AMARILLO STATE: TX ZIP: 79101 BUSINESS PHONE: 8063782121 MAIL ADDRESS: STREET 1: PO BOX 1261 CITY: AMARILLO STATE: TX ZIP: 79170 10-Q 1 NCE, PSCO AND SPS 3RD QTR 10-Q FOR 1999 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 September 30, 1999 OR [ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from _____________ to ____________ Exact name of registrant as specified in its charter, State or other jurisdiction of incorporation or organization, Address of principal executive offices and Registrant's Telephone Number, including area code Commission IRS Employer File Number Identification No. 1-12927 NEW CENTURY ENERGIES, INC. 84-1334327 (a Delaware Corporation) 1225 17th Street Denver, Colorado 80202 Telephone (303) 571-7511 1-3280 PUBLIC SERVICE COMPANY OF COLORADO 84-0296600 (a Colorado Corporation) 1225 17th Street Denver, Colorado 80202 Telephone (303) 571-7511 1-3789 SOUTHWESTERN PUBLIC SERVICE COMPANY 75-0575400 (a New Mexico Corporation) Tyler at Sixth Amarillo, Texas 79101 Telephone (303) 571-7511 ------------------- 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 On November 10, 1999, 115,549,242 shares of the Registrant's Common Stock were outstanding. The aggregate market value of this common stock held by nonaffiliates based on the closing price on the New York Stock Exchange was approximately $3,762,572,193. Public Service Company of Colorado and Southwestern Public Service Company meet the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and are therefore filing this Form 10-Q with the reduced disclosure format specified in General Instruction H (2) to such Form 10-Q. Table of Contents PART I - FINANCIAL INFORMATION Item l. Financial Statements .............................................. 1 Item 2.Management's Discussion and Analysis of Financial Condition and Results of Operations ...................................... 41 PART II - OTHER INFORMATION Item 1. Legal Proceedings................................................. 62 Item 6. Exhibits and Reports on Form 8-K.................................. 62 This combined Form 10-Q is separately filed by New Century Energies, Inc., Public Service Company of Colorado and Southwestern Public Service Company. Information contained herein relating to any individual company is filed by such company on its own behalf. Each registrant makes representations only as to itself and makes no other representations whatsoever as to information relating to the other registrants. This report should be read in its entirety. No one section of the report deals with all aspects of the subject matter. FORWARD-LOOKING INFORMATION The following discussions include "forward-looking statements"within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. Investors and prospective investors are cautioned that the forward-looking statements contained herein with respect to the revenues, earnings, capital expenditures, resolution and impact of litigation, Year 2000 issues, competitive performance, or other prospects for the business of New Century Energies, Inc., Public Service Company of Colorado and/or Southwestern Public Service Company or their affiliated companies, including any and all underlying assumptions and other statements that are other than statements of historical fact, may be influenced by factors that could cause actual outcomes and results to be materially different than projected. Such factors include, but are not limited to, the effects of weather, future economic conditions, the performance of generating units, fuel prices and availability, regulatory decisions and the effects of changes in state and federal laws, the pace of deregulation of domestic retail natural gas and electricity markets, the timing and extent of change in commodity prices for all forms of energy, capital spending requirements, the evolution of competition, earnings retention and dividend payout policies, changes in accounting standards, the consummation of the proposed merger with Northern States Power Company and/or other factors. From time to time, New Century Energies, Inc., Public Service Company of Colorado and Southwestern Public Service Company may publish or otherwise make available forward-looking statements. All such subsequent forward-looking statements, whether written or oral and whether made by or on behalf of each company, are also expressly qualified by these cautionary statements. i TERMS The abbreviations or acronyms used in the text and notes are defined below: Abbreviation or Acronym Term AEP......................................................American Electric Power CERCLA.....................................Comprehensive Environmental Response, Compensation and Liability Act Cheyenne..................................Cheyenne Light, Fuel and Power Company CPUC....................The Public Utilities Commission of the State of Colorado Denver District Court..............................District Court in and for the City and County of Denver DOE.........................................................Department of Energy DSM.......................................................Demand Side Management Dth....................................................................Dekatherm EPA.........................................U.S. Environmental Protection Agency e prime...........................................e prime, inc. and subsidiaries FERC........................................Federal Energy Regulatory Commission Fort St. Vrain.......................Fort St. Vrain Electric Generating Station, formerly a nuclear generating station Fuelco..........Fuel Resources Development Co., a dissolved Colorado Corporation GCA..........................................................Gas Cost Adjustment ICA....................................................Incentive Cost Adjustment IRS.....................................................Internal Revenue Service Kwh................................................................kilowatt-hour PSCo/SPS Merger........................business combination between PSCo and SPS Natural Fuels..........................................Natural Fuels Corporation NCE or Company........................................New Century Energies, Inc. NCE/NSP Merger..........................business combination between NCE and NSP NC Enterprises..............................................NC Enterprises, Inc. NCI..............................................New Century International, Inc. NMPRC....................................New Mexico Public Regulation Commission NOx...............................................................Nitrogen Oxide NSP................................................Northern States Power Company PCB.....................................................Polychlorinated Biphenyl PSCo..........................................Public Service Company of Colorado PSRI.......................................................PSR Investments, Inc. PUHCA.....................Public Utility Holding Company Act of 1935, as amended PRPs.............................................Potentially Responsible Parties PSCCC.............................................PS Colorado Credit Corporation PUCT..........................................Public Utility Commission of Texas QF...........................................................Qualifying Facility Quixx.........................................Quixx Corporation and subsidiaries SEC...........................................Securities and Exchange Commission SO2...............................................................Sulfur Dioxide SPS..........................................Southwestern Public Service Company SFAS 71.....................Statement of Financial Accounting Standards No. 71 - "Accounting for the Effects of Certain Types of Regulation" SFAS 112...................Statement of Financial Accounting Standards No. 112 - "Employers' Accounting for Postemployment Benefits" SFAS 121...................Statement of Financial Accounting Standards No. 121 - "Accounting for the Impairment of Long-Lived Assets and Long-Lived Assets to Be Disposed Of" Thunder Basin.........................................Thunder Basin Coal Company UE..............................Utility Engineering Corporation and subsidiaries WGI.....................................................WestGas InterState, Inc. Y2K....................................................................Year 2000 Yorkshire Electricity............................Yorkshire Electricity Group plc Yorkshire Power.......................................Yorkshire Power Group Ltd. ii NEW CENTURY ENERGIES, INC. AND SUBSIDIARIES CONSOLIDATED CONDENSED BALANCE SHEETS (Unaudited) (Thousands of Dollars) ASSETS September 30, December 31, 1999 1998 ---- ---- Property, plant and equipment, at cost: Electric ........................................ $7,388,462 $7,097,070 Gas.............................................. 1,283,045 1,210,605 Steam and other.................................. 108,478 111,620 Common to all departments........................ 462,408 423,287 Construction in progress......................... 393,405 391,100 ------- ------- 9,635,798 9,233,682 Less: accumulated depreciation .................. 3,486,585 3,351,659 --------- --------- Total property, plant and equipment............ 6,149,213 5,882,023 --------- --------- Investments, at cost: Investment in Yorkshire Power and other unconsolidated subsidiaries (Note 3)........... 358,069 340,874 Other............................................. 85,406 64,562 ------- ------ Total investments................................ 443,475 405,436 ------- ------- Current assets: Cash and temporary cash investments................ 40,513 56,667 Accounts receivable, less reserve for uncollectible accounts ($4,809 at September 30, 1999; $4,842 at December 31, 1998). ............................. 401,029 319,145 Accrued unbilled revenues.......................... 181,955 130,455 Recoverable purchased gas and electric energy costs 28,645 66,154 Materials and supplies, at average cost............ 78,226 69,298 Fuel inventory, at average cost.................... 30,338 24,653 Gas in underground storage, at cost (LIFO)......... 54,688 52,624 Prepaid expenses and other......................... 71,997 83,561 ------- ------ Total current assets.............................. 887,391 802,557 ------- ------- Deferred charges: Regulatory assets (Note 1)......................... 351,155 381,632 Unamortized debt expense........................... 28,697 27,408 Other.............................................. 240,300 172,908 ------- ------- Total deferred charges............................ 620,152 581,948 ------- ------- $8,100,231 $7,671,964 ========== ========== The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 1 NEW CENTURY ENERGIES, INC. AND SUBSIDIARIES CONSOLIDATED CONDENSED BALANCE SHEETS (Unaudited) (Thousands of Dollars) CAPITAL AND LIABILITIES September 30, December 31, 1999 1998 ---- ---- Common stock.......................................... $1,905,862 $1,866,386 Retained earnings..................................... 788,613 740,677 Accumulated other comprehensive income (Note 1)....... 4,757 7,764 ------- ------ Total common equity............................... 2,699,232 2,614,827 PSCo and SPS obligated mandatorily redeemable preferred securities of subsidiary trusts holding solely subordinated debentures of PSCo and SPS (Note 7)............................................ 294,000 294,000 Long-term debt of subsidiaries ....................... 2,272,069 2,205,545 --------- --------- 5,265,301 5,114,372 --------- --------- Noncurrent liabilities: Employees' postretirement benefits other than pensions ........................................ 56,199 61,732 Employees' postemployment benefits ................ 31,237 31,326 ------ ------ Total noncurrent liabilities...................... 87,436 93,058 ------ ------ Current liabilities: Notes payable and commercial paper ................ 521,091 524,394 Long-term debt due within one year................. 333,640 138,165 Accounts payable................................... 360,410 285,080 Dividends payable.................................. 69,869 69,271 Recovered electric energy costs.................... 9,538 18,760 Customers' deposits................................ 30,590 30,793 Accrued taxes...................................... 92,016 85,384 Accrued interest................................... 45,202 50,229 Other.............................................. 121,678 122,747 ------- ------- Total current liabilities......................... 1,584,034 1,324,823 --------- --------- Deferred credits: Customers' advances for construction............... 59,090 55,400 Unamortized investment tax credits ................ 97,099 100,925 Accumulated deferred income taxes.................. 952,742 947,247 Other.............................................. 54,529 36,139 ------- ------ Total deferred credits............................ 1,163,460 1,139,711 --------- --------- Commitments and contingencies (Notes 4 and 5)......... ---------- ---------- $8,100,231 $7,671,964 ========== ========== The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 2 NEW CENTURY ENERGIES, INC. AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF INCOME (Unaudited) (Thousands of Dollars) Three Months Ended September 30, 1999 1998 ---- ---- Operating revenues: Electric........................................... $701,483 $760,120 Gas................................................ 88,420 96,857 Other.............................................. 22,984 15,907 ------- ------ 812,887 872,884 Operating expenses: Fuel used in generation............................ 190,195 200,039 Purchased power.................................... 139,817 199,340 Cost of gas sold................................... 38,911 51,385 Other operating and maintenance expenses-regulated. 124,696 135,237 Other operating and maintenance expenses-nonregulated 25,661 22,614 Depreciation and amortization...................... 70,777 65,520 Taxes (other than income taxes) ................... 31,451 34,576 ------- ------ 621,508 708,711 ------- ------- Operating income...................................... 191,379 164,173 Other income and deductions: Equity in earnings of Yorkshire Power and other unconsolidated subsidiaries (Note 3)............. 2,221 10,247 Miscellaneous income and deductions - net.......... 806 905 ------- ------ 3,027 11,152 Interest charges and preferred dividends of subsidiaries: Interest on long-term debt......................... 45,932 42,737 Other interest..................................... 8,321 7,602 Allowance for borrowed funds used during construction ..................................... (3,727) (3,962) Dividends on PSCo and SPS obligated mandatorily redeemable preferred securities of subsidiary trusts holding solely subordinated debentures of PSCo and SPS...................................... 5,763 5,763 ----- ----- 56,289 52,140 ------ ------ Income before income taxes............................ 138,117 123,185 Income taxes.......................................... 40,190 32,413 ------- ------ Net income............................................ $97,927 $90,772 ======= ======= Weighted average common shares outstanding: Basic.............................................. 115,386 111,606 Diluted............................................ 115,399 111,722 Basic and diluted earnings per share of common stock outstanding $ 0.85 $ 0.82 ====== ======= The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 3 NEW CENTURY ENERGIES, INC. AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF INCOME (Unaudited) (Thousands of Dollars) Nine Months Ended September 30, 1999 1998 ---- ---- Operating revenues: Electric........................................... $1,903,291 $1,987,778 Gas................................................ 566,727 574,640 Other.............................................. 58,398 57,442 ------- ------ 2,528,416 2,619,860 Operating expenses: Fuel used in generation............................ 476,901 512,238 Purchased power.................................... 397,696 470,302 Cost of gas sold................................... 372,492 380,641 Other operating and maintenance expenses-regulated. 391,162 403,917 Other operating and maintenance expenses-nonregulated 74,652 64,582 Depreciation and amortization...................... 210,174 195,012 Taxes (other than income taxes) ................... 106,548 100,492 ------- ------- 2,029,625 2,127,184 --------- --------- Operating income...................................... 498,791 492,676 Other income and deductions: Equity in earnings of Yorkshire Power and other unconsolidated subsidiaries (Note 3).............. 15,245 6,430 Miscellaneous income and deductions - net.......... (5,345) (1,040) ------- ------ 9,900 5,390 Interest charges and preferred dividends of subsidiaries: Interest on long-term debt......................... 131,284 125,928 Other interest..................................... 22,572 25,054 Allowance for borrowed funds used during construction ..................................... (9,254) (12,883) Dividends on PSCo and SPS obligated mandatorily redeemable preferred securities of subsidiary trusts holding solely subordinated debentures of PSCo and SPS...................................... 17,288 11,799 Dividend requirements and redemption premium on preferred stock of subsidiaries.................. - 5,332 ---- ----- 161,890 155,230 ------- ------- Income before income taxes............................ 346,801 342,836 Income taxes.......................................... 98,339 109,322 ------- ------- Net income............................................ $248,462 $233,514 ======== ======== Weighted average common shares outstanding: Basic.............................................. 115,053 111,320 Diluted............................................ 115,079 111,463 Basic and diluted earnings per share of common stock outstanding $ 2.16 $ 2.10 ====== ======= The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 4 NEW CENTURY ENERGIES, INC. AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) (Thousands of Dollars) Nine Months Ended September 30, 1999 1998 ---- ---- Operating activities: Net income......................................... $248,462 $233,514 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization.................... 220,299 203,036 Amortization of investment tax credits........... (3,826) (3,836) Deferred income taxes............................ 18,699 (12,328) Equity in earnings of Yorkshire Power and other unconsolidated subsidiaries, net............... (15,245) (6,430) Allowance for equity funds used during construction (1,069) - Change in accounts receivable.................... (81,436) 7,220 Change in inventories............................ (16,911) (7,002) Change in other current assets................... (2,424) 67,840 Change in accounts payable....................... 72,792 (62,319) Change in other current liabilities.............. (13,553) 50,545 Change in deferred amounts....................... (58,637) 22,398 Change in noncurrent liabilities................. (5,622) 10,347 Other............................................ (464) (8) ------- ------- Net cash provided by operating activities...... 361,065 502,977 Investing activities: Construction expenditures.......................... (476,125) (411,778) Allowance for equity funds used during construction 1,069 - Proceeds from disposition of property, plant and equipment ................................... 2,726 3,755 Acquisition and disposition of subsidiaries, net of cash acquired or sold (Note 3)................... 13,877 (13,725) Purchase of other investments...................... (17,217) (4,006) Sale of other investments.......................... 13,703 6,313 ------ ----- Net cash used in investing activities.......... (461,967) (419,441) Financing activities: Proceeds from sale of common stock................. 29,965 34,280 Proceeds from sale of PSCo obligated mandatorily redeemable preferred securities................... - 187,700 Proceeds from sale of long-term debt............... 356,335 247,961 Redemption of long-term debt....................... (98,321) (156,838) Short-term borrowings - net........................ (3,303) (25,036) Redemption of preferred stock (Note 1)............. - (181,824) Dividends on common stock.......................... (199,928) (191,575) -------- -------- Net cash provided by (used in) financing activities ................................ 84,748 (85,332) ------ ------ Net decrease in cash and temporary cash investments ................................ (16,154) (1,796) Cash and temporary cash investments at beginning of period ........................ 56,667 72,623 ------ ------ Cash and temporary cash investments at end of period .................................. $ 40,513 $ 70,827 ======== ======== The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements 5 NEW CENTURY ENERGIES, INC. AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF SHAREHOLDERS' EQUITY Three Months Ended September 30, 1999 and 1998 (Unaudited) (Thousands of Dollars, Except Share Information)
Accumulated Paid Other Common Stock, $1 par value in Retained Comprehensive Shares Amount Capital Earnings Income Total ------ ------ ------- -------- ------ ----- Balance at June 30, 1998 111,491,918 $ 111,492 $1,615,789 $ 672,718 $ 5,624 $2,405,623 Comprehensive income (Note 1): Net income.......... - - - 90,772 - 90,772 Foreign currency translation adjustment......... - - - - 8,656 8,656 ----- Comprehensive income 99,428 Dividends declared on common stock - - - (64,805) - (64,805) Issuance of common stock 239,041 239 10,065 - - 10,304 ------- ------- ------- ------- ------- ------ Balance at September 30,1998 111,730,959 $ 111,731 $1,625,854 $ 698,685 $ 14,280 $2,450,550 =========== ========== ========== ========= ========= ========== Balance at June 30, 1999 115,242,268 $ 115,242 $1,780,974 $ 757,695 $ (9,410) $2,644,501 Comprehensive income (Note 1): Net income.......... - - - 97,927 - 97,927 Foreign currency translation adjustment......... - - - - 14,167 14,167 ------ Comprehensive income 112,094 Dividends declared on common stock - - - (67,009) - (67,009) Repurchase of common stock (34,360) (34) (1,207) - - (1,241) Issuance of common stock 325,796 326 10,561 - - 10,887 ------- ------- ------- ------- ------- ------ Balance at September 30,1999 115,533,704 $ 115,534 $1,790,328 $788,613 $ 4,757 $ 2,699,232 =========== ========== ========== ======== ======== ============
Authorized shares of common stock were 260 million at September 30, 1999 and 1998. The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 6 NEW CENTURY ENERGIES, INC. AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF SHAREHOLDERS' EQUITY Nine Months Ended September 1999 and 1998 (Unaudited) (Thousands of Dollars, Except Share Information)
Accumulated Paid Other Common Stock, $1 par value in Retained Comprehensive Shares Amount Capital Earnings Income Total ------ ------ ------- -------- ------ ----- Balance at December 31, 1997 110,749,301 $ 110,749 $1,583,446 $659,050 $4,142 $2,357,387 Comprehensive income (Note 1): Net income.......... - - - 233,514 - 233,514 Foreign currency translation adjustment......... - - - - 10,138 10,138 ------- Comprehensive income 243,652 Dividends declared on common stock - - - (193,879) - (193,879) Issuance of common stock 981,658 982 42,408 - - 43,390 ------- ------- ------- ------- ------- ------ Balance at September 30,1998 111,730,959 $ 111,731 $1,625,854 $698,685 $ 14,280 $2,450,550 =========== ========== ========== ======== ======== ========== Balance at December 31, 1998 114,490,772 $ 114,491 $1,751,895 $740,677 $ 7,764 $2,614,827 Comprehensive income (Note 1): Net income.......... - - - 248,462 - 248,462 Foreign currency translation adjustment......... - - - - (3,007) (3,007) ------- Comprehensive income 245,455 Dividends declared on common stock - - - (200,526) - (200,526) Repurchase of common stock (34,360) (34) (1,207) - - (1,241) Issuance of common stock 1,077,292 1,077 39,640 - - 40,717 --------- ------- ------ ----- ------ ------ Balance at September 30,1999 115,533,704 $ 115,534 $1,790,328 $788,613 $ 4,757 $2,699,232 =========== ========== ========== ======== ======== ==========
Authorized shares of common stock were 260 million at September 30, 1999 and 1998. The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 7 PUBLIC SERVICE COMPANY OF COLORADO AND SUBSIDIARIES CONSOLIDATED CONDENSED BALANCE SHEETS (Unaudited) (Thousands of Dollars) ASSETS September 30, December 31, 1999 1998 ---- ---- Property, plant and equipment, at cost: Electric ..................................... $4,548,872 $4,369,134 Gas........................................... 1,237,877 1,171,198 Steam and other............................... 58,407 71,986 Common to all departments..................... 456,752 418,484 Construction in progress...................... 300,288 264,752 -------- -------- 6,602,196 6,295,554 Less: accumulated depreciation ............... 2,327,156 2,241,165 --------- --------- Total property, plant and equipment......... 4,275,040 4,054,389 --------- --------- Investments, at cost: Note receivable from affiliate (Note 3)....... 192,620 192,620 Other......................................... 11,475 22,664 -------- -------- Total investments............................ 204,095 215,284 -------- -------- Current assets: Cash and temporary cash investments........... 14,617 19,926 Accounts receivable, less reserve for uncollectible accounts ($3,057 at September 30, 1999; $2,254 at December 31, 1998) ..... 170,382 172,587 Accrued unbilled revenues .................... 126,775 119,856 Recoverable purchased gas and electric energy costs ...................................... 20,590 62,761 Materials and supplies, at average cost....... 54,427 47,881 Fuel inventory, at average cost............... 28,043 22,361 Gas in underground storage, at cost (LIFO).... 53,676 51,779 Prepaid expenses and other.................... 35,350 46,523 -------- ------ Total current assets......................... 503,860 543,674 -------- ------- Deferred charges: Regulatory assets (Note 1).................... 242,988 269,112 Unamortized debt expense ..................... 18,974 17,874 Other......................................... 84,289 77,303 -------- -------- Total deferred charges....................... 346,251 364,289 -------- -------- $5,329,246 $5,177,636 ========== ========== The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 8 PUBLIC SERVICE COMPANY OF COLORADO AND SUBSIDIARIES CONSOLIDATED CONDENSED BALANCE SHEETS (Unaudited) (Thousands of Dollars) CAPITAL AND LIABILITIES September 30, December 31, 1999 1998 ---- ---- Common stock....................................... $1,302,119 $1,302,119 Retained earnings.................................. 338,519 325,213 -------- ------- Total common equity............................ 1,640,638 1,627,332 PSCo obligated mandatorily redeemable preferred securities of subsidiary trust holding solely subordinated debentures of PSCo (Note 7) ........ 194,000 194,000 Long-term debt..................................... 1,619,008 1,643,130 --------- --------- 3,453,646 3,464,462 --------- --------- Noncurrent liabilities: Employees' postretirement benefits other than pensions ..................................... 48,979 55,537 Employees' postemployment benefits.............. 27,195 27,195 ------ ------ Total noncurrent liabilities................... 76,174 82,732 ------ ------ Current liabilities: Notes payable and commercial paper.............. 396,300 402,795 Long-term debt due within one year.............. 241,856 44,481 Accounts payable................................ 213,328 226,712 Dividends payable............................... 44,575 46,461 Recovered electric energy costs................. 9,538 - Customers' deposits............................. 23,894 23,902 Accrued taxes................................... 45,543 57,848 Accrued interest................................ 34,010 36,729 Current portion of accumulated deferred income taxes ........................................ 5,422 8,142 Other........................................... 69,363 68,729 -------- ------- Total current liabilities...................... 1,083,829 915,799 --------- ------- Deferred credits: Customers' advances for construction............ 57,702 54,260 Unamortized investment tax credits ............. 90,877 94,459 Accumulated deferred income taxes............... 541,320 538,581 Other........................................... 25,698 27,343 -------- ------- Total deferred credits......................... 715,597 714,643 -------- ------- Commitments and contingencies (Notes 4 and 5)...... ---------- ---------- $5,329,246 $5,177,636 ========== ========== The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 9 PUBLIC SERVICE COMPANY OF COLORADO AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF INCOME (Unaudited) (Thousands of Dollars) Three Months Ended September 30, 1999 1998 ---- ---- Operating revenues: Electric........................................... $400,892 $466,221 Gas................................................ 82,471 74,635 Other.............................................. 837 745 ------- ------- 484,200 541,601 Operating expenses: Fuel used in generation............................ 60,583 61,019 Purchased power.................................... 114,004 182,852 Gas purchased for resale........................... 34,900 32,928 Other operating and maintenance expenses........... 93,098 99,529 Depreciation and amortization...................... 50,332 45,344 Taxes (other than income taxes) ................... 17,527 21,279 Income taxes ..................................... 23,172 21,816 ------- ------- 393,616 464,767 ------- ------- Operating income...................................... 90,584 76,834 Other income and deductions - net..................... 114 3,558 Interest charges: Interest on long-term debt......................... 32,430 30,781 Other interest..................................... 7,710 4,816 Allowance for borrowed funds used during construction (2,991) (3,020) Dividends on PSCo obligated mandatorily redeemable preferred securities of subsidiary trust holding solely subordinated debentures of PSCo (Note 7) 3,800 3,800 ----- ----- 40,949 36,377 ------ ------ Net income............................................ $49,749 $44,015 ======= ======= The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 10 PUBLIC SERVICE COMPANY OF COLORADO AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF INCOME (Unaudited) (Thousands of Dollars) Nine Months Ended September 30, 1999 1998 ---- ---- Operating revenues: Electric........................................... $1,155,904 $1,211,607 Gas................................................ 477,537 473,288 Other.............................................. 5,794 5,946 ------- ------- 1,639,235 1,690,841 Operating expenses: Fuel used in generation............................ 167,330 161,202 Purchased power.................................... 340,194 430,783 Gas purchased for resale........................... 295,462 293,468 Other operating and maintenance expenses........... 289,646 296,038 Depreciation and amortization...................... 147,694 135,035 Taxes (other than income taxes) ................... 64,609 62,185 Income taxes ..................................... 67,154 72,184 ------- ------- 1,372,089 1,450,895 --------- --------- Operating income...................................... 267,146 239,946 Other income and deductions: Equity earnings in Yorkshire Power (Note 3)........ - 3,446 Miscellaneous income and deductions - net.......... (621) 2,641 ---- ----- (621) 6,087 Interest charges: Interest on long-term debt......................... 92,221 90,047 Other interest..................................... 19,671 14,967 Allowance for borrowed funds used during construction (7,275) (8,712) Dividends on PSCo obligated mandatorily redeemable preferred securities of subsidiary trust holding solely subordinated debentures of PSCo (Note 7).. 11,400 5,911 ------- ------ 116,017 102,213 ------- ------- Net income............................................ 150,508 143,820 Dividend requirements and redemption premium on preferred stock .................................... - 5,332 ----- ----- Earnings available for common stock................... $150,508 $138,488 ======== ======== The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 11 PUBLIC SERVICE COMPANY OF COLORADO AND SUBSIDIARIES CONSOLIDATED CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) (Thousands of Dollars) Nine Months Ended September 30, 1999 1998 ---- ---- Operating activities: Net income......................................... $150,508 $143,820 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization.................... 154,207 139,227 Amortization of investment tax credits........... (3,582) (3,591) Deferred income taxes............................ 8,333 (14,798) Equity in earnings of Yorkshire Power............ - (3,446) Change in accounts receivable.................... 2,205 37,457 Change in inventories............................ (14,125) (4,984) Change in other current assets................... 46,425 60,580 Change in accounts payable....................... (13,384) (61,444) Change in other current liabilities.............. (4,860) 18,111 Change in deferred amounts....................... (3,515) (16,389) Change in noncurrent liabilities................. (6,558) 10,834 ------- ------- Net cash provided by operating activities...... 315,654 305,377 Investing activities: Construction expenditures.......................... (370,148) (338,663) Proceeds from disposition of property, plant and equipment ...................................... 13,242 6,207 Purchase of other investments...................... (1,689) (466) Sale of other investments.......................... 12,878 4,394 ------- ------- Net cash used in investing activities.......... (345,717) (328,528) Financing activities: Proceeds from the sale of PSCo obligated mandatorily redeemable preferred securities.................. - 187,700 Proceeds from the sale of long-term debt........... 243,270 247,274 Redemption of long-term debt....................... (72,932) (156,414) Short-term borrowings - net........................ (6,495) 67,600 Dividends on common stock.......................... (139,089) (121,790) Redemption of preferred stock (Note 7)............. - (181,824) Dividends and redemption premium on preferred stock (Note 7) ........................................ - (8,261) ------- ------ Net cash provided by financing activities...... 24,754 34,285 ------- ------- Net increase (decrease) in cash and temporary cash investments ............................. (5,309) 11,134 Cash and temporary cash investments at beginning of period .......................... 19,926 18,909 ------ ------ Cash and temporary cash investments at end of period ....................................... $ 14,617 $ 30,043 ======== ======== The accompanying notes to consolidated condensed financial statements are an integral part of these financial statements. 12 SOUTHWESTERN PUBLIC SERVICE COMPANY CONDENSED BALANCE SHEETS (Unaudited) (Thousands of Dollars) ASSETS September 30, December 31, 1999 1998 ---- ---- Property, plant and equipment, at cost: Electric........................................... $2,777,837 $2,665,115 Construction in progress........................... 89,619 121,407 ------ ------- 2,867,456 2,786,522 Less: accumulated depreciation..................... 1,104,908 1,057,183 --------- --------- Total property, plant and equipment............... 1,762,548 1,729,339 --------- --------- Investments, at cost: Notes receivable from affiliate.................... 119,036 119,036 Other.............................................. 5,717 5,591 ------- ------- Total investments................................. 124,753 124,627 ------- ------- Current assets: Cash and temporary cash investments................ 12,384 1,350 Accounts receivable, less reserve for uncollectible accounts ($1,362 at September 30,1999; $1,695 at December 31, 1998)... ........................... 90,041 76,190 Accrued unbilled revenues.......................... 54,427 9,373 Recoverable electric energy cost................... 7,434 - Materials and supplies, at average cost............ 18,085 16,970 Fuel inventory, at average cost.................... 2,295 2,293 Current portion of accumulated deferred income taxes - 6,113 Prepaid expenses and other......................... 4,306 5,248 ------- ------- Total current assets.............................. 188,972 117,537 ------- ------- Deferred charges: Regulatory assets (Note 1)......................... 107,740 111,971 Unamortized debt expense........................... 8,854 8,767 Other.............................................. 58,111 37,623 ------- ------- Total deferred charges............................ 174,705 158,361 ------- ------- $2,250,978 $2,129,864 ========== ========== The accompanying notes to condensed financial statements are an integral part of these financial statements. 13 SOUTHWESTERN PUBLIC SERVICE COMPANY CONDENSED BALANCE SHEETS (Unaudited) (Thousands of Dollars) CAPITAL AND LIABILITIES September 30, December 31, 1999 1998 ---- ---- Common stock.......................................... $348,402 $348,402 Retained earnings..................................... 415,299 389,818 ------- ------- Total common equity............................... 763,701 738,220 SPS obligated mandatorily redeemable preferred securities of subsidiary trust holding solely subordinated debentures of SPS (Note 7) 100,000 100,000 Long-term debt........................................ 605,840 530,618 ------- ------- 1,469,541 1,368,838 --------- --------- Noncurrent liabilities: Employees' postretirement benefits other than pensions 6,823 5,941 Employees' postemployment benefits................. 3,482 3,571 ------- ------- Total noncurrent liabilities...................... 10,305 9,512 ------- ------- Current liabilities: Notes payable and commercial paper................. 103,391 85,162 Note payable to affiliate.......................... - 9,000 Long-term debt due within one year................. 90,113 90,113 Accounts payable................................... 89,215 64,275 Dividends payable.................................. 20,912 20,007 Recovered electric energy costs.................... - 18,760 Customers' deposits................................ 6,105 5,904 Accrued taxes...................................... 28,303 37,646 Accrued interest................................... 10,863 12,273 Current portion of accumulated deferred income taxes 2,810 - Other.............................................. 20,633 18,011 ------- ------- Total current liabilities......................... 372,345 361,151 ------- ------- Deferred credits: Unamortized investment tax credits................. 5,031 5,219 Accumulated deferred income taxes.................. 383,805 380,655 Other.............................................. 9,951 4,489 ------- ------- Total deferred credits............................ 398,787 390,363 ------- ------- Commitments and contingencies (Notes 4 and 5)......... ---------- ---------- $2,250,978 $2,129,864 ========== ========== The accompanying notes to condensed financial statements are an integral part of these financial statements. 14 SOUTHWESTERN PUBLIC SERVICE COMPANY CONDENSED STATEMENTS OF INCOME (Unaudited) (Thousands of Dollars) Three Months Ended September 30, 1999 1998 ---- ---- Operating revenues.................................... $290,587 $284,648 Operating expenses: Fuel used in generation............................ 130,067 139,021 Purchased power.................................... 18,019 9,946 Other operating and maintenance expenses........... 29,910 34,189 Depreciation and amortization...................... 18,450 17,754 Taxes (other than income taxes).................... 13,208 12,525 Income taxes....................................... 25,020 21,755 ------- ------- 234,674 235,190 ------- ------- Operating income...................................... 55,913 49,458 Other income and deductions - net..................... 2,349 2,233 Interest charges: Interest on long-term debt......................... 13,055 11,553 Other interest..................................... 1,440 2,163 Allowance for borrowed funds used during construction (730) (917) Dividends on SPS obligated mandatorily redeemable preferred securities of subsidiary trust holding solely subordinated debentures of SPS 1,963 1,963 ----- ----- 15,728 14,762 ------ ------ Net income............................................ $42,534 $36,929 ======= ======= The accompanying notes to condensed financial statements are an integral part of these financial statements. 15 SOUTHWESTERN PUBLIC SERVICE COMPANY CONDENSED STATEMENTS OF INCOME (Unaudited) (Thousands of Dollars) Nine Months Ended September 30, 1999 1998 ---- ---- Operating revenues.................................... $717,253 $748,386 Operating expenses: Fuel used in generation............................ 310,095 351,036 Purchased power.................................... 34,528 19,666 Other operating and maintenance expenses........... 97,572 103,650 Depreciation and amortization...................... 55,357 53,291 Taxes (other than income taxes) ................... 39,079 35,918 Income taxes ...................................... 52,868 54,709 ------- ------- 589,499 618,270 ------- ------- Operating income...................................... 127,754 130,116 Other income and deductions - net..................... 6,809 5,571 Interest charges: Interest on long-term debt......................... 37,889 34,654 Other interest..................................... 3,989 7,275 Allowance for borrowed funds used during construction (1,963) (4,115) Dividends on SPS obligated mandatorily redeemable preferred securities of subsidiary trust holding solely subordinated debentures of SPS ............ 5,888 5,888 ----- ----- 45,803 43,702 ------ ------ Net income............................................ $88,760 $91,985 ======= ======= The accompanying notes to condensed financial statements are an integral part of these financial statements. 16 SOUTHWESTERN PUBLIC SERVICE COMPANY CONDENSED STATEMENTS OF CASH FLOWS (Unaudited) (Thousands of Dollars) Nine Months Ended September 30, 1999 1998 ---- ---- Operating activities: Net income......................................... $88,760 $91,985 Adjustments to reconcile net income to net cash provided by operating activities: Depreciation and amortization.................... 58,301 56,593 Amortization of investment tax credits........... (188) (188) Deferred income taxes............................ 13,868 (1,524) Allowance for funds used during construction..... (1,075) - Change in accounts receivable.................... (13,851) (2,065) Change in inventories............................ (1,117) (994) Change in other current assets................... (51,546) 18,915 Change in accounts payable....................... 24,940 (32,346) Change in other current liabilities.............. (26,690) 19,565 Change in deferred amounts....................... (14,111) 38,588 Change in noncurrent liabilities................. 793 (989) ------- ------- Net cash provided by operating activities...... 78,084 187,540 Investing activities: Construction expenditures.......................... (88,247) (64,838) Allowance for equity funds used during construction 1,075 - Cost of disposition of property, plant and equipment (1,719) (2,345) Purchase and sale of other investments............. (126) 186 ------- ------- Net cash used in investing activities.......... (89,017) (66,997) Financing activities: Proceeds from sale of long-term debt............... 99,846 - Redemption of long-term debt....................... (24,733) (58) Short-term borrowings - net........................ 9,229 (44,297) Dividends on common stock.......................... (62,375) (71,527) ------- ------- Net cash provided by (used in) financing activities 21,967 (115,882) ------ -------- Net increase in cash and temporary cash investments 11,034 4,661 Cash and temporary cash investments at beginning of period ................................... 1,350 986 ----- --- Cash and temporary cash investments at end of period ................................... $ 12,384 $ 5,647 ======== ======= The accompanying notes to condensed financial statements are an integral part of these financial statements 17 NEW CENTURY ENERGIES, INC. AND SUBSIDIARIES NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS (Unaudited) 1. Summary of Significant Accounting Policies (NCE, PSCo and SPS) Business, Utility Operations and Regulation NCE is a registered holding company under the PUHCA and its domestic utility subsidiaries (PSCo, SPS and Cheyenne) are engaged principally in the generation, purchase, transmission, distribution and sale of electricity and in the purchase, transportation, distribution and sale of natural gas. Both the Company and its subsidiaries are subject to the regulatory provisions of the PUHCA. The utility subsidiaries are subject to regulation by the FERC and state utility commissions in Colorado, Texas, New Mexico, Wyoming, Kansas and Oklahoma. Over 90% of the Company's revenues are derived from its regulated utility operations. Regulatory Assets and Liabilities The Company's regulated subsidiaries prepare their financial statements in accordance with the provisions of SFAS 71, as amended. SFAS 71 recognizes that accounting for rate regulated enterprises should reflect the relationship of costs and revenues introduced by rate regulation. A regulated utility may defer recognition of a cost (a regulatory asset) or recognize an obligation (a regulatory liability) if it is probable that, through the ratemaking process, there will be a corresponding increase or decrease in revenues. Accounting under SFAS 71 is appropriate as long as: rates are established by or subject to approval by independent, third party regulators; rates are designed to recover an enterprise's cost-of-service; and in view of the demand for service, it is reasonable to assume that rates are set at levels that will recover costs and can be collected from customers. While deregulation legislation has been enacted in certain states where SPS operates (see Note 4. Regulatory Matters), the Company currently believes its utility subsidiaries will continue to be subject to rate regulation. In the event that a portion of a subsidiaries' operations is no longer subject to the provisions of SFAS 71, as a result of a change in regulation or the effects of competition, the Company's subsidiaries could be required to write-off their regulatory assets, determine any impairment to other assets resulting from deregulation and write-down any impaired assets to their estimated fair value, which could separately have a material adverse effect on NCE's, PSCo's and/or SPS's financial position, results of operations or cash flows. The following regulatory assets are reflected in the Company's consolidated balance sheets (in thousands): September 30, 1999 NCE PSCo SPS ------ ------ ------ Income taxes........................ $138,360 $ 61,555 $ 77,321 Nuclear decommissioning costs....... 62,113 62,113 - Employees' postretirement benefits other than pensions............... 54,329 51,543 2,786 Employees' postemployment benefits.. 24,526 24,127 - Demand-side management costs........ 31,699 27,414 4,285 Unamortized debt reacquisition costs 32,345 14,733 17,069 Other............................... 7,783 1,503 6,279 ------ ------ ------ Total............................. $351,155 $242,988 $107,740 ======== ======== ======== 18 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) December 31, 1998 NCE PSCo SPS ------ ------ ------ Income taxes........................ $148,499 $ 69,868 $ 79,116 Nuclear decommissioning costs....... 69,490 69,490 - Employees' postretirement benefits other than pensions............... 57,350 54,461 2,889 Employees' postemployment benefits.. 24,888 24,416 - Demand-side management costs........ 37,160 31,984 5,176 Unamortized debt reacquisition costs 33,138 15,769 16,808 Other............................... 11,107 3,124 7,982 ------ ------ ------ Total............................. $381,632 $269,112 $111,971 ======== ======== ======== The regulatory assets of the Company's regulated subsidiaries that are currently being recovered as of September 30, 1999 and December 31, 1998 are reflected in rates charged to customers. The recovery of regulatory assets over the next three years is estimated to exceed $130 million. Refer to the discussion below or the Notes to Consolidated Financial Statements included herein and in the NCE, PSCo and SPS 1998 Annual Report on Form 10-K for a more detailed discussion regarding recovery periods. On January 27, 1997, the CPUC issued its order on PSCo's 1996 gas rate case. The CPUC allowed recovery of postemployment benefits on an accrual basis under SFAS 112 and denied amortization of the approximately $8.9 million regulatory asset recognized upon the adoption of SFAS 112. PSCo has appealed in the Denver District Court the decision related to this issue. PSCo believes that it will be successful on appeal and that the associated regulatory asset is realizable. On April 1, 1998, in connection with PSCo's annual electric department earnings test filing, PSCo requested approval to recover its electric jurisdictional portion of this regulatory asset totaling approximately $15 million over three years. In December 1998, the CPUC approved a settlement agreement on this matter, which deferred the final determination of the regulatory treatment of these costs pending the outcome of the current appeal of the decision on PSCo's gas rate case. PSCo believes that it will be allowed recovery of SFAS 112 costs on an accrual basis. If PSCo is ultimately unsuccessful in its appeal of the gas rate case decision and/or in its request to recover its electric jurisdictional regulatory asset, all unrecoverable amounts will be written off (see Note 4. Regulatory Matters). PSCo recovered its FERC jurisdictional portion of this regulatory asset. Other Property Property, plant and equipment includes approximately $18.4 million and $25.4 million, respectively, for costs associated with the engineering design of the future Pawnee 2 generating station and certain water rights located in southeastern Colorado, also obtained for a future generating station. PSCo is earning a return on these investments based on its weighted average cost of debt in accordance with a CPUC rate order. Non-utility Subsidiaries and International Investments The Company's non-utility subsidiaries are principally involved in energy-related businesses including the following: engineering, design and construction management, energy marketing and trading, non-regulated energy services, the management of real estate and certain life insurance policies, the financing of certain current assets of PSCo and investments in cogeneration facilities, electric wholesale generators and a foreign utility company. The Company's international investments are subject to applicable regulation in the countries in which such investments are made (see Note 3. Investment in Yorkshire Power). Financial statements of foreign subsidiaries are translated into U.S. dollars at current rates, except for revenues, costs and expenses, which are translated at average current rates during each reporting period. 19 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) Consolidation and Financial Statement Presentation The Company follows the practice of consolidating the accounts of its majority owned and controlled subsidiaries. The Company recognizes equity in earnings from its unconsolidated investments accounted for under the equity method of accounting. All intercompany items and transactions have been eliminated. Energy Trading Activities The Company and its subsidiaries adopted Emerging Issues Task Force Issue No. 98-10, "Accounting for Energy Trading and Risk Management Activities" ("EITF 98-10"), effective January 1, 1999. EITF 98-10 requires gains or losses resulting from market value changes on energy trading contracts to be recorded in earnings. The initial adoption of EITF 98-10 had no impact on the net income of NCE, PSCo or SPS. For the three and nine month periods ended September 30, 1999, NCE recognized net gains of $759,000 and $208,000, respectively, and PSCo recognized net losses of $330,000 and $252,000, respectively, for market value changes on energy trading contracts. SPS does not currently have any trading activities. Revenues and purchased energy costs associated with trading activities are presented net on the income statement in electric and gas revenues. Certain prior year amounts have been reclassified for comparative purposes. Comprehensive Income The Company and its subsidiaries adopted Statement of Financial Accounting Standards No. 130, "Reporting Comprehensive Income," effective January 1, 1998. This statement establishes standards for the reporting and display of comprehensive income (net income plus all other changes in net assets from non-owner sources) and its components in financial statements. Comprehensive income and its components were reported in NCE's Consolidated Condensed Statements of Shareholders' Equity for the three and nine month periods ended September 30, 1999. Other comprehensive income consists solely of foreign currency translation adjustments related to the investment in Yorkshire Power. For the three and nine month periods ended September 30, 1999, PSCo and SPS had no comprehensive income items, therefore, comprehensive income equals net income. For the same periods in 1998, SPS had no comprehensive income items, therefore, comprehensive income equals net income. For the three months ended September 30, 1998, PSCo had no comprehensive income items, therefore, comprehensive income equals net income. PSCo's comprehensive income for the nine months ended September 30, 1998, was impacted solely by activity occurring in the three month period ended March 31, 1998. During the first quarter of 1998, PSCo had a foreign currency translation adjustment of $5.3 million related to the investment in Yorkshire Power, included in comprehensive income. On March 31, 1998, PSCo sold NCI (which includes Yorkshire Power and related foreign currency translation adjustments) to NC Enterprises. The amount of the sale included the accumulated other comprehensive income of $9.4 million at March 31, 1998. As a result of this sale, PSCo had no accumulated other comprehensive income at March 31, 1998, and for all subsequent periods. Basic and Diluted Earnings Per Share Basic earnings per share is based upon the weighted average common shares outstanding during the periods presented. Diluted earnings per share reflects the potential dilution that could occur if securities or other agreements to issue common stock were exercised or converted into common stock. Diluted earnings per share is based upon the weighted average common and common equivalent shares outstanding during periods presented. 20 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) Employee stock options are the Company's only common stock equivalents. There are no other potentially dilutive securities. The potentially dilutive securities included in the computation of diluted earnings per share were 13,000 and 26,000 for the three and nine month periods ended September 30, 1999, respectively, and 116,000 and 143,000 for the three and nine month periods ended September 30, 1998, respectively. These shares had no impact on the Company's reported earnings per share information. Approximately 2,130,000 common shares are issuable under stock option grants as of September 30, 1999, but were not included in the computation of diluted earnings per share because the options' exercise prices were greater than the average market price of the common stock. Statements of Cash Flows - Non-cash Transactions: Shares of common stock (200,880 in 1999 and 222,362 in 1998), valued at the market price on the date of issuance (approximately $10 million in 1999 and 1998), were issued to a savings plan of the Company. The estimated issuance values were recognized in other operating expenses during the respective preceding years. The stock issuances were non-cash financing activities and are not reflected in the consolidated condensed statements of cash flows. Effective July 1, 1999, the Company sold all of the outstanding common stock of Texas-Ohio Gas, Inc. (see Note 6. Acquistions and Divestitures). The changes in current assets, current liabilities and deferred amounts for periods prior to this sale are reflected in operating activities on the NCE Consolidated Condensed Statement of Cash Flows. General See Note 1. of the Notes to Consolidated Financial Statements in the NCE, PSCo and SPS 1998 Annual Report on Form 10-K for a summary of the companies and their subsidiaries significant accounting policies. 2. Proposed Merger with Northern States Power Company (NCE, PSCo and SPS) On March 24, 1999, NCE and NSP, entered into an Agreement and Plan of Merger (the "NCE/NSP Merger Agreement") providing for a strategic business combination of NCE and NSP. Pursuant to the NCE/NSP Merger Agreement, NCE will be merged with and into NSP with NSP as the surviving corporation in the merger and the holding company for the combined assets and operations. NSP will be renamed Xcel Energy Inc. ("Xcel Energy"). Concurrently with the closing of the NCE/NSP Merger, NSP will contribute all of its utility assets, other than shares that it owns in subsidiaries, to a newly formed wholly-owned subsidiary. At the same time, the new subsidiary will assume all of NSP's liabilities associated with the assets that it receives in the contribution. If difficulties arise in obtaining the approvals and consents required to transfer NSP's utility assets to a new utility subsidiary, NCE and NSP may negotiate a mutually acceptable alternative. Subject to the terms of the NCE/NSP Merger Agreement, at the time of the NCE/NSP Merger, each share of NCE common stock, par value $1.00 per share ("NCE Common Stock") (other than certain shares to be canceled), together with any associated purchase rights, will be converted into the right to receive 1.55 shares of Xcel Energy common stock, par value $2.50 per share ("Xcel Energy Common Stock"). Cash will be paid in lieu of any fractional shares of Xcel Energy Common Stock which holders of NCE Common Stock would otherwise receive. Based on outstanding common stock of NCE and NSP at September 30, 1999, the NCE/NSP Merger would result in the common shareholders of NCE owning 54% of the common equity of Xcel Energy and the common shareholders of NSP owning 46% of the common equity of Xcel Energy. The NCE/NSP Merger is expected to be a tax-free stock-for-stock exchange for shareholders of both companies and to be accounted for as a pooling-of-interests. 21 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) It is anticipated that Xcel Energy will initially adopt the NCE dividend payment level, adjusted for the exchange ratio, resulting in a pro forma dividend of $1.50 per share on an annual basis, following completion of the NCE/NSP Merger. The actual dividend level will be dependent upon the combined company's results of operations, financial position, cash flows and other factors, and will be evaluated by the Board of Directors of Xcel Energy. NCE and NSP estimate regulated cost savings of approximately $1.1 billion, net of merger costs and costs to achieve the savings, in the first 10 years after the transaction is completed. Nonrecurring costs directly attributable to the NCE/NSP Merger are being deferred by NCE. These costs are expected to be amortized to expense by the Company's utility subsidiaries in periods subsequent to the consummation of the merger consistent with the anticipated recovery in rates. The shareholders of the Company and NSP approved the Agreement and Plan of Merger on June 28, 1999. Additionally, consummation of the NCE/NSP Merger is subject to certain closing conditions, including, among others, approval or completion of regulatory review by certain state utility regulators, the SEC under the PUHCA, the FERC, the Nuclear Regulatory Commission, the Federal Communications Commission and expiration or termination of the waiting period applicable to the NCE/NSP Merger under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended. Applications or submissions to the state utility regulators, where required, and the FERC were completed in July 1999. In general, such filings propose the sharing of cost savings among customers and shareholders for up to five years. The required authorizations from the state utility regulators in Kansas and Wisconsin have been obtained and orders are expected from state regulators in Arizona and Oklahoma by year-end. Hearings have been scheduled during the first quarter of 2000 in Colorado, Minnesota, New Mexico, North Dakota, Texas and Wyoming and orders are expected by the end of the second quarter of 2000. NCE and NSP are negotiating with the parties to certain protests filed with the FERC to resolve any significant concerns and allow the FERC's review to proceed expeditiously. NCE and NSP also have each agreed to certain undertakings and limitations regarding the conduct of their respective businesses prior to the closing of the transaction. The NCE/NSP Merger is expected to take another 9 to 12 months to complete. A merger integration team, consisting of executives from each company, was formed and is overseeing merger-related activities and the future integration of operations of NCE and NSP. It is Management's intention that the combined company will begin realizing certain savings upon the consummation of the NCE/NSP Merger. The following unaudited summarized pro forma financial information gives effect to the NCE/NSP Merger as if it had occurred at September 30, 1999 for balance sheet information and at January 1, 1999 for income statement information. This financial information should be read in conjunction with the historical financial statements and related notes of NCE and NSP, which are included in the Annual Reports on Form 10-K and Quarterly Reports on Form 10-Q of the respective companies. The unaudited summarized pro forma financial information has been prepared using information provided by NSP. This information does not necessarily indicate what the combined company's financial position or operating results would have been if the merger had been completed on the assumed completion dates and does not necessarily indicate future operating results of the combined company. 22 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) Unaudited Summarized Pro Forma Balance Sheet information as of September 30, 1999 (in millions): NSP NCE Adjustments Pro Forma --- --- ----------- --------- Utility plant - net..... $4,400 $6,149 $1,236 $11,785 Current assets.......... 892 887 - 1,779 Other assets............ 3,393 1,064 (1,236) 3,221 ------ ------ ------ ------ Total assets.......... $8,685 $8,100 $ - $16,785 ====== ====== ====== ======= Common equity........... $2,548 $2,699 $ - $ 5,247 Preferred securities.... 305 294 - 599 Long-term debt.......... 2,393 2,272 - 4,665 ------ ------ ------ ------ Total capitalization.. 5,246 5,265 - 10,511 Current liabilities..... 1,919 1,584 - 3,503 Other liabilities....... 1,520 1,251 - 2,771 ------ ------ ------ ------ Total equity and liabilities ....... $8,685 $8,100 $ - $ 16,785 ====== ====== ====== ======== The unaudited pro forma balance sheet information at September 30, 1999 reflects reporting adjustments to conform the presentation of nonregulated property (in property, plant and equipment). Unaudited Summarized Pro Forma Income Statement information for the nine months ended September 30 (in millions): 1999 NSP NCE Adjustments Pro Forma --- --- ----------- --------- Revenues................ $2,216 $2,528 $ 357 $5,101 Operating income........ 276 499 166 941 Net income.............. 175 248 - 423 Earnings available for common ............... 171 248 - 419 Earnings per share...... $1.12 $2.16 - $1.27 1998 Revenues................ $2,106 $2,620 $ 195 $4,921 Operating income........ 279 493 127 899 Net income.............. 194 234 - 428 Earnings available for common ................ 189 234 - 423 Earnings per share...... $1.26 $ 2.10 - $1.31 The unaudited pro forma income statement information for the nine months ended September 30, 1999 and 1998 reflect reporting adjustments to conform the presentation of nonregulated revenues and equity earnings in operating revenues. 3. Investment in Yorkshire Power (NCE and PSCo) Yorkshire Power is a joint venture initially equally owned by PSCo and AEP, which acquired indirectly all of the outstanding ordinary shares of Yorkshire Electricity, a United Kingdom ("U.K.") regional electricity company. NCI accounts for its investment in Yorkshire Power using the equity method and NCI's equity in earnings of Yorkshire Power is 50%, the same as its ownership share. In August 1999, the Office of Gas and Electricity Markets ("Ofgem"), the body appointed by the U.K. government to regulate the gas and electricity industries in the U.K., published draft price proposals for the U.K.'s regional electric distribution businesses that would be effective for the five-year period beginning April 1, 2000 23 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) and provide for price reductions of 15% to 20% in Yorkshire Power's distribution revenues. Yorkshire Power filed comments on September 17, 1999 with Ofgem, primarily dealing with Ofgem's analysis used in the development of the recommendations included in the August price proposals. On October 8, 1999, Ofgem issued an update to its August proposals which provided for a 15% reduction in Yorkshire Power's distribution revenues and a further 8% transfer of costs to Yorkshire Power's electricity supply business. Additionally, on October 8, 1999, Ofgem issued draft electricity supply price proposals. The proposals provide for a supply price cap for domestic U.K. consumers which would apply for two years from April 2000 until March 2002 and would not apply to small industrial and commercial customers, where the market was sufficiently competitive. These new supply proposals for Yorkshire Power provide for a real price reduction of approximately 10.7% (of which 7.3% is due to lower distribution use of system charges arising from the distribution price control review) on the standard domestic tariff and a nominal price freeze from April 2001 ending in March 2002. If Yorkshire Power does not agree with Ofgem's proposed public electricity supplier ("PES") license amendment resulting from either the distribution or supply price control review then the regulator may refer the proposals to the Competition Commission. Following the publication of the Competition Commission's report, the regulator may make appropriate modifications to Yorkshire Power's PES License. Ofgem is expected to publish final proposals on both the distribution and the supply businesses at the end of November 1999. Yorkshire Power's management intends to take all available opportunities to grow revenues and reduce costs to mitigate the impact of the final Ofgem distribution and supply price proposals. Should Yorkshire Power be unable to grow revenues and reduce costs to the extent required to offset the effect of the price proposals, the Company's equity earnings from its investment in Yorkshire Power will be reduced in comparison to its current level of earnings. Effective March 31, 1998, PSCo sold its common stock investment in NCI to NC Enterprises, a NCE subsidiary. NCI's primary investment is Yorkshire Power. PSCo received as consideration a 20-year promissory note from NC Enterprises in the amount of approximately $292.6 million of which $192.6 remains outstanding at September 30, 1999. Annual interest payments are required for the first three years followed by principal and interest payments for the remaining seventeen years. The interest rate on the note is 7.02%. In October 1998, NCE contributed $100 million to NC Enterprises, which was used to reduce the principal balance of the promissory note to PSCo. NCE intends to make additional capital contributions to NC Enterprises to provide the necessary cash flow requirements to make payments on the promissory note to PSCo. Summarized income statement information for the nine months ended September 30, 1999 and 1998, respectively is presented below (in millions): 1999 1998 ---- ---- Yorkshire Power: Operating revenues....................... $1,679.7 $1,677.3 -------- -------- Operating income......................... 200.5 264.8 -------- ----- Net income............................... $ 38.5 $ 13.6 ======== ======== NCI's equity in earnings of Yorkshire Power $ 19.2 $ 6.8 ======== ======== NCI's equity in earnings of Yorkshire Power increased by approximately $12.4 million for the nine months ended September 30, 1999, when compared to the same period in 1998, primarily due to the impact of one-time items recognized in 1998. In the second quarter of 1998, Yorkshire Power recognized an impairment of its investment in Ionica, a wireless telecommunications company, upon the May 22, 1998, announcement by Ionica that negotiations for release of lines of credit from existing providers of bank finance had been unsuccessful. In November 1998, Ionica was placed into receivership and an administrator was appointed to oversee its operations and distribute its remaining assets. The impairment, reflecting a write down to fair market value, was offset, in part, by an unrelated tax adjustment. These two items reduced NCI's equity earnings in Yorkshire Power by approximately $16 million. The investment in Ionica was subsequently sold with no further adverse financial impact. 24 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) The unaudited pro forma financial information, for the nine months ended September 30, 1998, presented below for PSCo assumes that NCI was sold to NC Enterprises, effective January 1, 1998. The pro forma adjustments represent the removal of NCI's net income from PSCo and the inclusion of interest income, net of tax, from the promissory note to PSCo from NC Enterprises. Based upon the above assumptions, shown below is unaudited pro forma financial information for the nine months ended September 30, 1998 (in millions): PSCo Earnings 1998 ---- Net income............................................... $143.8 Pro forma adjustments: NCI's net income....................................... (2.8) Interest income from promissory note, net of tax....... 3.2 ----- Pro forma result......................................... $144.2 ====== 4. Regulatory Matters (NCE, PSCo and SPS) Electric Utility Matters PSCo Performance Based Regulatory Plan PSCo's base electric rates are based on traditional cost of service ratemaking principles. The CPUC established a performance based regulatory plan in connection with the CPUC's decision to approve the PSCo/SPS Merger. The major components of this regulatory plan include the following: - - an annual electric department earnings test with the sharing of earnings in excess of an 11% return on equity for the calendar years 1997-2001; - - a Quality of Service Plan ("QSP") designed with performance measures to effectively penalize or reward PSCo based on the quality of service provided to retail customers. Subsequent to the approval of the performance based regulatory plan, the reward structure was eliminated for the years 1999-2001; and - - an Incentive Cost Adjustment ("ICA") which provides for the sharing of energy costs and savings relative to an annual target cost/delivered Kwh. PSCo filed with the CPUC its proposed Performance Based Regulatory Plan adjustment for calendar year 1998. This adjustment provides the means for implementing the sharing mechanism for the customers' portion of earnings over PSCo's authorized return on equity threshold. PSCo recorded an estimated refund obligation of $8 million for the 1998 earnings test. Hearings related to the final determination of sharing of 1998 earnings, by the CPUC, are scheduled for November 1999. Since July 1998, PSCo has been refunding amounts related to its earnings test refund obligation to customers through bill credits. PSCo's believes that any obligations related to the sharing of earnings or the QSP will not have a materially adverse affect on PSCo's financial condition or position. Additionally, PSCo agreed to freeze base electric rates after the PSCo/SPS Merger rate reductions for the period through December 31, 2001 with the flexibility to make certain other rate changes, including those necessary for the recovery of DSM, QF capacity costs and decommissioning costs. The freeze in base electric rates does not prohibit PSCo from filing a general rate case or deny any party the opportunity to initiate a complaint or show cause proceeding. 25 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) PSCo Wholesale - FERC On March 30, 1999, PSCo received authorization from the FERC to engage in market-based wholesale power sales. The authorization allows PSCo to sell energy to e prime, subject to certain conditions, as well as third parties. SPS Merger Related Rate Reductions Under the various regulatory commission approvals, SPS is required to provide credits to customers over five years from the date of the PSCo/SPS Merger, August 1, 1997, for one-half of the measured non-fuel operation and maintenance expense savings associated with the PSCo/SPS Merger. SPS will provide guaranteed minimum annual credits to retail customers of $3 million in Texas, $100,000 in Oklahoma and $10,000 in Kansas and $1.5 million to wholesale customers. Under a settlement reached with the NMPRC, effective December 30, 1998, SPS discontinued the merger savings credit of $1.2 million per year with the implementation of new retail rates in New Mexico as discussed below. SPS Electric Cost Adjustment Mechanisms Substantially all fuel and purchased power costs are recoverable from utility customers, as determined on a jurisdictional basis, using approved cost adjustment mechanisms. Texas The PUCT's regulations require periodic examination of SPS's fuel and purchased power costs, the efficiency of the use of such fuel and purchased power, fuel acquisition and management policies and purchase power commitments. SPS is required to file an application for the Commission to retrospectively review, at least every three years, the operations of a utility's electricity generation and fuel management activities. In June 1998, SPS filed its reconciliation for the generation and fuel management activities totaling approximately $690 million, for the period from January 1995 through December 1997. For this same period, SPS had approximately $21.4 million in underrecovered fuel costs associated with the Texas retail jurisdiction. SPS has entered into a settlement agreement with the General Counsel of the PUCT, which, if approved, would provide for the recovery of substantially all fuel costs. The final outcome of this fuel reconciliation proceeding is pending. Various parties in the proceedings are contesting the settlement agreement, which includes the recovery of the Thunder Basin costs discussed below. Hearings were held in October 1999. It is anticipated that a decision will be issued during the first quarter of 2000. SPS was named as a defendant in a case entitled Thunder Basin Coal Co. vs. Southwestern Public Service Co. In November 1994, the jury returned a verdict in favor of Thunder Basin and awarded damages of approximately $18.8 million. SPS appealed the judgment and, in January 1997, that Court found in favor of Thunder Basin and upheld the judgment. In February 1997, SPS recorded the liability for the judgment including interest and court costs. The amount of approximately $22.3 million was paid in April 1997. During 1996 and 1997, SPS obtained conditional approval from the FERC to collect portions of the Thunder Basin judgment from wholesale customers and the NMPRC issued an order granting recovery of the New Mexico retail jurisdictional portion of the judgment. In May 1997, SPS filed a request with the PUCT to surcharge undercollected fuel and purchased power expenses, which included $9.1 million of the Thunder Basin judgment. The PUCT issued a decision, which denied recovery of the judgment through a surcharge on the grounds that the costs were not classified as fuel costs. In 1997, SPS expensed approximately $12.1 million of the Texas retail jurisdictional portion of the Thunder Basin judgment and recognized an equal amount as deferred revenue in anticipation of future recovery through the pending fuel reconciliation proceeding. 26 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) SPS believes that recovery of the Thunder Basin costs for the Texas retail jurisdiction will be approved in the pending fuel reconciliation proceeding. Under the PUCT regulations, a utility may recover eligible fuel expenses or fuel-related expenses, which result in benefits to customers that exceed the costs that customers would otherwise have to pay. The Thunder Basin costs resulted in total net savings to customers of approximately $8.5 million, with approximately $4.6 million net savings attributable to Texas retail jurisdictional customers. In the previously discussed proposed settlement agreement with the General Counsel's office at the PUCT, the General Counsel has agreed with SPS's proposed recovery of the Thunder Basin costs. Effective in April 1999, the PUCT authorized SPS to reduce its fixed fuel factor for SPS's Texas retail jurisdiction, by approximately $44 million on an annual basis. The PUCT also authorized SPS to refund its over collected fuel costs for the period January 1998 through January 1999. This one-time $16 million fuel refund, including interest, was applied to the monthly billings during April 1999. This rate reduction and fuel cost refund are primarily due to lower coal transportation costs between SPS's coal supplier and the railroad company which began in late 1998. New Mexico In October 1997, the NMPRC approved a fixed fuel factor for SPS's New Mexico retail jurisdiction, effective January 1998. This employs an over/under fuel collection calculation made on a monthly basis. SPS is required to petition for a change in the fixed fuel factor if the over/under recovery balance exceeds $5 million. In addition, on an annual basis, SPS files with the NMPRC a report of SPS's fuel and purchase power costs, which includes the current over/under recovery balance and proposed rate changes to refund or surcharge the balance. The methodology of the over/under calculation, plus interest, is similar to the Texas fixed fuel factor calculation. In January 1999, SPS implemented new annual fixed fuel cost recovery factors to reflect lower fuel costs primarily as a result of the previously discussed coal transportation cost settlement between SPS's coal supplier and the railroad company. SPS Rate Cases New Mexico In November 1997, the NMPRC issued an order investigating SPS's rates. In the order, the NMPRC determined that because of the rapid changes occurring in the electric industry the NMPRC would require rate case filings by the major electricity suppliers who have not adopted a plan to provide retail open access and customer choice of suppliers. SPS made a compliance filing in May 1998, which proposed a $1.7 million annual rate reduction for certain retail customers in New Mexico and incorporated the $1.2 million guaranteed minimum annual credits, discussed above. In October 1998, SPS entered into an uncontested stipulation agreement settling the rate investigation case. As part of this settlement, SPS instituted a $6 million annual reduction in base rates (discontinuing the $1.2 million in guaranteed minimum annual credits) for certain retail customers. Additionally, SPS implemented full normalization in its accounting for income taxes with recovery of the New Mexico jurisdictional portion of the tax regulatory asset over 16.8 years. On November 30, 1998, the NMPRC approved the stipulation and the new rates became effective December 30, 1998. Wholesale - FERC In 1989, the FERC issued its final order regarding a 1985 wholesale rate case. SPS appealed certain portions of that order that related to recognition of rates for the reduction of the federal income tax rates from 46% to 34%. The United States Court of Appeals remanded the case, directing the FERC to reconsider SPS's claim. Negotiated settlements with certain customers were reached, and approved by the FERC, in 1993 and 1995, with SPS receiving approximately $10 million, including interest. Settlement agreements were reached with the two remaining customers during 1998 and approved by the FERC. In June 1998, SPS recorded $7.7 million of additional revenues in connection 27 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) with the settlement. For the year ended December 31, 1998, SPS recorded $16.9 million of additional revenues and $7.6 million of additional depreciation expense. Cheyenne Rate Case On August 13, 1999, Cheyenne filed a combined gas and electric rate case with the Public Service Commission of Wyoming ("WPSC") requesting a $2.3 million increase in electric and a $1.3 million increase in gas base rates, including a 12% return on equity. This follows the expiration of the two-year moratorium on filing rate cases in connection with the WPSC approval of the PSCo/SPS Merger. Hearings are scheduled to begin in January 2000. Cheyenne intends to pursue settlement discussions. Deregulation Legislation (NCE and SPS) New Mexico On April 8, 1999, New Mexico enacted the Electric Utility Restructuring Act of 1999, which allows customer choice for residential, small commercial and educational customers beginning January 1, 2001. All remaining customers will be allowed customer choice on January 1, 2002. Customers of a municipal utility and customers of a distribution cooperative utility will be afforded choice only if the respective utility elects to participate. The legislation provides for recovery of no less than 50% of stranded costs quantified by the NMPRC. Transition costs must be approved by the NMPRC prior to being recovered through a non-by-passable wires charge, which must be included in a transition plan filing. All public electric utilities operating in New Mexico must file a transition plan with the NMPRC by March 1, 2000. Before January 1, 2001, SPS must separate its utility operations into at least two segments: a) energy generation services and b) transmission and distribution (including retail operations) services either by the creation of separate affiliates that may be owned by a common holding company or by the sale of assets to one or more third parties. A regulated company will be prohibited from providing unregulated services. Texas On June 18, 1999, an electric utility restructuring act ("SB-7") was passed in Texas, which allows for retail competition, for most areas of the state, beginning January 1, 2002. The legislation requires, among other things, a rate freeze for all customers, effective September 1, 1999 until January 1, 2002 together with an annual earning test; a 6% rate reduction for those residential and small commercial customers who choose not to switch suppliers at the start of retail competition; the unbundling of business activities, costs and rates relating to generation, transmission and distribution and retail services; reductions in NOx and SO2 emissions and the recovery of stranded costs. The PUCT can delay the date for retail competition if a power region is unable to offer fair competition and reliable service during pilot projects which begin for all utilities on June 1, 2001 for 5% of the utility's combined load of all customer classes. As part of the above Texas legislation, SPS is required to file a separation plan, on January 10, 2000, for the unbundling of business activities relating to 1) generation, 2) transmission and distribution and 3) retail services. The plan is to be implemented on January 1, 2002. Also, SPS is required to file a rate case on April 1, 2000 to set the rates for the transmission and distribution services, which are to be unbundled and implemented on January 1, 2002. The Company is evaluating the effect of these filings on SPS. The legislation specifically addresses competition in the Texas Panhandle, where SPS operates, recognizing that certain transmission constraints exist within the region that require full retail customer choice to develop on a more structured schedule than the rest of the state. SPS must file a transition to competition plan with the PUCT by December 1, 2000. SPS, with no estimated stranded costs, must direct any excess earnings indicated in the annual earnings tests during the period January 1, 1999 through December 31, 2001 to improvements in transmission and distribution facilities, to capital expenditures to improve air quality or to accelerate the amortization of regulatory assets (subject to PUCT approval). 28 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) Additionally, the Texas legislation requires that no generation company can own and control more than 20% of the installed capacity located in or capable of delivering electricity to a power region. Utilities owning more than 400 Mw must auction entitlements to at least 15% of the utility's installed generation capacity used for providing electric services to Texas retail customers. The capacity entitlement auctions are to continue for 5 years or until 40% of the utility's residential and small commercial customers served prior to the start date of competition are served by non-affiliated companies. The legislation includes several possible remedies to market power abuses. These provisions are not immediately applicable to SPS due to the existing transmission constraints and market power issues in the Panhandle region. In connection with the NCE/NSP Merger approval proceedings, the Company filed supplemental testimony with the PUCT in October 1999 outlining its plan to address the various provisions of SB-7. In general, the plan presented by the Company provides for the transfer of ownership or control of 595 Mw of generating capacity (either through capacity entitlement auction or divesting) to other competitors and the addition of transmission lines to import an additional 400 Mw from other geographic regions. The major components of this plan include the following: - - auction entitlements (409 Mw or 15 percent of installed generation capacity) to capacity owned and controlled by SPS, that is dedicated to serving Texas retail customers, by January 1, 2002. The Company would continue to own and operate the capacity, but competitors would have the right to dispatch the power. - - divest 186 Mw of SPS-area generating capacity by January 1, 2002 in order to further reduce market dominance, - - separate SPS existing competitive functions beginning September 1, 2000, - - unbundle SPS into three separate companies beginning January 1, 2002, and - - implement a pilot program for retail access for at least 5 percent of its Texas retail load in June 2001 and to expand the pilot program to 20% of customer load in 2002. Most of the other Texas utilities will be moving to full customer choice in 2002. The SPS plan is designed to address the market power issues related to the deregulation legislation and would promote further competition before the end of 2006 by allowing only competitors to build new plants in the region between now and then, by adding even more transmission lines, and possibly by further divesting some generation. Hearings on the NCE/NSP Merger are scheduled to begin in late February, 2000 and the final order is expected in the second quarter of 2000. Financial Reporting Considerations The Emerging Issues Task Force of the Financial Accounting Standards Board reached a consensus in Issue No. 97-4, "Deregulation of the Pricing of Electricity" ("EITF 97-4") indicating that when deregulatory legislation is passed or when a rate order (whichever is necessary to effect change in the jurisdiction) that contains sufficient detail for an enterprise to reasonably determine how the transition plan will affect the separable portion of its business whose pricing is being deregulated is issued, the enterprise should stop applying SFAS 71 to that separable portion of its business. While legislation has been enacted in Texas and New Mexico, there are several unresolved issues that will significantly impact how and when deregulation related to the generation portion of the business, will be implemented by SPS. It is expected that SPS will discontinue the application of SFAS 71 related to the generation portion of the business when the provisions of EITF 97-4 have been met. Gas Utility Matters PSCo Rate Cases In November 1998, PSCo filed a retail gas rate case with the CPUC requesting an annual increase in rates of approximately $23.4 million. The request for a rate increase reflects revenues for additional plant investment, a 12.0% 29 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) return on equity and the recovery of incremental year 2000 costs (see Note 5. Commitments and Contingencies - Year 2000 Issue). On June 8, 1999, the CPUC approved an increase in base rates of approximately $15 million with an 11.25% return on equity, effective July 1, 1999. PSCo was also allowed recovery of certain environmental costs. Prudently incurred year 2000 costs will be recovered under a separate mechanism beginning in 2000. On June 5, 1996, PSCo filed a retail rate case with the CPUC requesting an annual increase in its jurisdictional gas department revenues equal to approximately $34 million. In early 1997, the CPUC approved an overall increase of approximately $18 million with an 11.25% return on equity, effective February 1, 1997 and as modified on May 15, 1997. The CPUC disallowed the recovery of certain postemployment benefit costs under SFAS 112 and imputed anticipated merger related savings net of costs (associated with the PSCo/SPS merger) related to the gas business (see Note 1. Summary of Significant Accounting Policies). PSCo filed a petition with the Denver District Court appealing the CPUC's decision. PSCo anticipates a decision during late 1999. PSCo Unbundling and Deregulation of the Retail Natural Gas Supply Business On April 26, 1999, the Colorado legislature approved a bill, which allows natural gas public utilities to voluntarily submit plans to the CPUC to open their markets and enable customers to choose their natural gas supplier. This bill was signed by the Governor on June 6, 1999. Currently, PSCo provides a traditional bundled gas service with rates designed for the recovery of actual gas costs through the GCA and for providing transportation and delivery services. Delivery of natural gas will continue to be regulated, with delivery companies required to offer nondiscriminatory pipeline access to competitors. PSCo will continue to be subject to the reporting requirements of SFAS 71 as a regulated distribution company. 5. Commitments and Contingencies (NCE, PSCo and SPS) Environmental Issues The Company and its subsidiaries are subject to various environmental laws, including regulations governing air and water quality and the storage and disposal of hazardous or toxic wastes. The Company and its subsidiaries assess, on an ongoing basis, measures to ensure compliance with laws and regulations related to air and water quality, hazardous materials and hazardous waste compliance and remediation activities. Environmental Site Cleanup As described below, PSCo has been or is currently involved with the cleanup of contamination from certain hazardous substances. In many situations, PSCo is pursuing or intends to pursue insurance claims and believes it will recover some portion of these costs through such claims. Additionally, where applicable, PSCo is pursuing, or intends to pursue, recovery from other PRPs and through the rate regulatory process. To the extent any costs are not recovered through the options listed above, PSCo would be required to recognize an expense for such unrecoverable amounts. Under the CERCLA, the EPA identified, and a Phase II environmental assessment revealed, low level, widespread contamination from hazardous substances at the Barter Metals Company ("Barter") properties located in central Denver. For an estimated 30 years, PSCo sold scrap metal and electrical equipment to Barter for reprocessing. PSCo has completed the cleanup of this site at a cost of approximately $9 million and has received responses from the Colorado Department of Public Health and Environment ("CDPHE") indicating that no further action is required related to these properties. In January 1996, a lawsuit by PSCo against its insurance providers, the Denver District Court entered final judgment in favor of PSCo in the amount of $5.6 million for certain cleanup costs at Barter. Several appeals and cross appeals have been filed by one of the insurance providers and PSCo in the Colorado Court of Appeals. The insurance provider has posted supersedeas bonds in the amount of $9.8 million including the judgement and interest. In July 1997, the Colorado Court of Appeals sent back to trial court the previously awarded judgment on the basis that the jury had not been properly instructed by the Judge regarding a narrow issue associated with certain policies. Previously, PSCo had received certain insurance settlement proceeds from other insurance providers for Barter and other 30 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) contaminated sites and a portion of those funds remains to be allocated to this site by the trial court. Both sides of the litigation filed petitions for certiorari to the Colorado Supreme Court, which granted a hearing on several issues. In September 1999, the Colorado Supreme Court held that PSCo was entitled to coverage on all policies, but that the trial court should have allocated the damages and self-insured retentions over the entire period the facilities were in operations. Although the Colorado Supreme Court remanded the judgement to the trial court for additional proceedings, it suggested that its ruling may reduce PSCo's available recovery to approximately $1.4 million. Settlement has been achieved with two small PRPs, although the Company has been ultimately unsuccessful recovering from the remaining has PRP's. In March 1998, PSCo sold the remaining Barter properties, and the total proceeds were $1.1 million. PSCo requested recovery of environmental costs of approximately $7.7 million related to Barter over four years, in its proposed Performance Based Regulatory Plan for calendar year 1998 (see Note 4. Regulatory Matters). PSCo has identified several other sites where clean up of hazardous substances may be required. While potential liability and settlement costs are still under investigation and negotiation, PSCo believes that the resolution of these matters will not have a material adverse effect on PSCo's financial position, results of operations or cash flows. PSCo will pursue the recovery of all significant costs incurred for such projects through insurance claims and/or the rate regulatory process. Other Environmental Matters Under the Clean Air Act Amendments of 1990 ("CAAA"), coal-fueled power plants are required to reduce SO2 and NOx emissions to specified levels through a phased approach. PSCo and SPS's facilities must comply with the Phase II requirements, which will be effective in the year 2000. Currently, these regulations permit compliance with SO2 emission limitations by using SO2 allowances allocated to plants by the EPA, using allowances generated by reducing emissions at existing plants and by using allowances purchased from other companies. The Company expects to meet the Phase II emission standards placed on SO2 and Nox through the combination of: (1) the use of low sulfur coal, (2) the operation of air quality control equipment on certain generation facilities, and (3) allowances issued by the EPA and purchased from other companies. PSCo has obtained all necessary conditions to proceed with its plans to spend approximately $211 million on its Denver and Boulder Metro area coal-fueled power plants to further reduce such emissions below the required regulatory levels discussed above. The cost of these controls will be recovered through rates. Hayden Steam Electric Generating Station In May 1996, PSCo and the other joint owners of Hayden Station reached an agreement resolving violations alleged in complaints filed by a conservation organization, the CDPHE and the EPA against the joint owners. PSCo is the operator and owns an average undivided interest of approximately 53% of the station's two generating units. In connection with the settlement, the joint owners of the Hayden station were required to install emission control equipment of approximately $130 million (PSCo's portion is approximately $70 million). The settlement included stipulated future penalties for failure to comply with the terms of the agreement, including specific provisions related to meeting construction deadlines associated with the installation of additional emission control equipment and complying with particulate, SO2 and NOx emissions limitations. In August 1996, the U.S. District Court for the District of Colorado entered the settlement agreement, which effectively resolved this litigation. Installation of certain portions of this emission control equipment has been completed with the remaining requirements in process and on schedule in accordance with the settlement agreement. The joint owners completed installation and began operating the emission control equipment required for Unit 1 on time in accordance with the settlement agreement in late 1998. In May 1999, Unit 2 began operating with the required particulate and NOx emission control equipment. The operation of SO2 emission control equipment has been delayed due to equipment problems. The joint owners have filed a notice of "force majeure" to excuse any equipment related delays. The joint owners will withdraw this notice if they resolve the equipment problems within the terms of the settlement agreement. 31 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) Craig Steam Electric Generating Station In October 1996, a conservation organization filed a complaint in the U. S. District Court pursuant to provisions of the Federal Clean Air Act (the "Act") against the joint owners of the Craig Steam Electric Generating Station located in western Colorado. Tri-State Generation and Transmission Association, Inc. is the operator of the Craig station and PSCo owns an undivided interest (acquired in April 1992) in each of two units at the station totaling approximately 9.7%. The plaintiff alleged that: (1) the station exceeded the 20% opacity limitations in excess of 14,000 six minute intervals during the period extending from the first quarter of 1991 through the second quarter of 1996, and (2) the owners failed to operate the station in a manner consistent with good air pollution control practices. The complaint seeks, among other things, civil monetary penalties and injunctive relief. The Act provides for penalties of up to $25,000 per day per violation, but the level of penalties imposed in any particular instance is discretionary. Settlement discussions were held in 1998, although no settlement was achieved. On March 8, 1999, the U. S. District Court ruled on all pending motions in the case. It held that: (1) the conservation organization has standing to bring the litigation; (2) the conservation organization may rely on continuous opacity monitor data to demonstrate the plant's violation of the opacity standard; (3) the Craig Station owners may challenge the accuracy of the monitor data at trial; and (4) the conservation organization must prove at trial that the station has not operated with good pollution control practices. The parties, the EPA and the CDPHE entered into mediation in an attempt to resolve all air quality matters related to the facility. Resolution of this matter may require the installation of additional emission control equipment. Management does not believe that any potential liability, the future impact of this litigation on plant operations, or any related cost will have a material adverse impact on PSCo's financial position, results of operations or cash flows. Fort St. Vrain PSCo has completed all decommissioning activities at Fort St. Vrain and the site has been released for unrestricted use. PSCo is currently operating a gas-fired combined cycle steam generation plant at this facility. Spent nuclear fuel is currently being stored on-site in the Independent Spent Fuel Storage Installation ("ISFSI"). In 1996, PSCo and the DOE entered into an agreement resolving all the defueling issues, as discussed in Notes to Consolidated Financial Statements in NCE's and PSCo's 1998 annual report on Form 10-K. On June 4, 1999, the Nuclear Regulatory Commission ("NRC") approved the transfer of the ISFSI to the DOE. The NRC has been notified by the DOE that license transfer activities have been completed. NRC has performed their final inspection of the ISFSI. All functions, responsibilities, ownership and liabilities now reside with the DOE. Tax Matters PSRI, a subsidiary of PSCo, owns and manages permanent life insurance policies on certain past and present employees. These corporate owned life insurance ("COLI") policies were entered into prior to July 1, 1986. In 1996, Congress passed legislation to phase out the tax benefits with certain COLI policies, however, PSCo's policies were grandfathered under this legislation. In August 1998, the IRS issued a Notice of Proposed Adjustment proposing to disallow the 1993 and 1994 deductions of interest expense related to policy loans on the COLI policies totaling approximately $54.6 million. A Request for Technical Advice from the IRS National Office with respect to the proposed adjustment is pending. Management is vigorously contesting this issue. PSCo has not recorded any provision for income tax or interest expense related to this matter. Management believes that PSCo's tax deduction of interest expense on life insurance policy loans was in full compliance with IRS regulations and believes that the resolution of this matter will not have a material adverse impact on PSCo's financial position, results of operations or cash flows. 32 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) Year 2000 Issue The Y2K issue is a result of a universal programming standard that records dates as six digits, e.g., mm/dd/yy, using only the last two digits for the year. Any automated system software or firmware that uses two-digit fields could understand the year 2000 as the year 1900 if the issue is not corrected. This situation is not limited to computers; it has the potential to affect many systems, components and devices, which have embedded computer chips, which may be date sensitive. The Y2K issue could result in a major system failure or miscalculations and does impact many NCE systems considered critical or important to the Company's business operations. Systems posing the greatest business risks to the Company include power generation and distribution systems, telecommunications systems, energy trading systems and billing systems. The Company is correcting all potential Y2K failure points identified in its critical automated systems to maintain service to its customers and to mitigate legal and financial risks. In 1997, the Company established the Y2K Program Office to oversee all corporate-wide Y2K initiatives. These initiatives encompass all computer software, embedded systems, as well as contingency planning. Teams of internal and external specialists were established to inventory and assess and test critical computer programs and automated operational systems and modify those that may not be Y2K compliant. The inventory and assessment phases for information technology ("IT") systems were completed in 1998. Remediation and testing phases for all critical IT systems were completed by June 30, 1999. For critical non-IT systems, which exist primarily in the generation, transmission and distribution areas of the business, the inventory, assessment, remediation and testing phases were also completed by June 30, 1999. NCE has achieved "Y2K Ready" status for all mission-critical electrical generating and transmission facilities. Readiness was accomplished by June 30, 1999, in accordance with the guidelines established by the North American Electric Reliability Council ("NERC"). NCE is a participant in the NERC Y2K Program that has established reporting criteria and milestone dates for electric utilities. The final step of this program was the submittal of a letter to the president of NERC, certifying that the company has met the NERC Y2K goal. NCE submitted its Y2K certification letter, without exceptions, with its June 1999 NERC report. In October 1999, NCE successfully completed an external review of NCE's Y2K program by an independent third party. The review criteria followed by the external review team were developed for the independent verification and validation study that NERC is conducting for the DOE. The Company has identified third parties, with which it has material business relationships including interconnected utilities, telecommunications service providers, fuel and water suppliers, equipment suppliers, leased facilities and financial institutions. Subject matter experts, along with functional managers, continue to evaluate the current list of third parties and have ongoing discussions with these and other critical suppliers about their Y2K readiness and contingency planning efforts. The Company currently expects to incur costs of approximately $17 million (approximately $13 million has been spent through September 30, 1999) in operating and capital expenditures to modify its computer software, hardware and other automated systems used in operations enabling proper data processing relating to the year 2000 and beyond. The Company has spent approximately $18 million in operating and capital expenditures for the accelerated replacement of certain non-compliant IT systems. PSCo and SPS have incurred the majority of these costs. The table below details the actual costs incurred during 1998 and prior periods; the actual costs incurred through the nine months ended September 30, 1999; and the estimated costs to be incurred during the remainder of 1999 and the first quarter of 2000. A significant portion of the remaining costs to be incurred consists of finalizing remaining work on nonmission-critical systems, testing, project management and contingency planning. 33 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued)
Remaining Estimated Actual Costs Actual Costs Estimated Costs Total Project 1998 and Prior 1999 to be Incurred Costs -------------- -------- -------------- ------- (in millions) Operating expenses.. $8.0 $3.9 $3.0 $14.9 Capital for automated system components 0.7 0.6 0.3 1.6 IT replacement projects: Operating...... 0.2 0.6 0.1 0.9 Capital........ 6.4 10.9 - 17.3 ---- ---- ---- ----- Total........ $15.3 $16.0 $3.4 $34.7 ===== ===== ==== =====
Yorkshire Power has also undertaken activities to address Y2K issues. The estimated proportionate share of Yorkshire's incremental Y2K costs (costs which would not have been required in the normal course of business) that will flow through to the Company's earnings as a result of such activities is not expected to have a material impact on the financial condition or results of operations of the Company. The most reasonably likely worst case scenario resulting during Y2K critical dates is a loss of production capacity from certain of the Company's generating units, along with loss of a portion of the communication system that is critical to generation and distribution control. If this were to occur, the Company's operating utilities may be required to "island" (separate from neighboring interconnected utilities) their generation and distribution systems in their service territories. As part of this scenario, difficulty could be encountered with the restart of generating units. The overall blackout recovery plan for NCE is designed so that this most reasonably likely worst case scenario would be addressed and electricity restored. Critical components of this plan have been and continue to be tested to provide assurance that the Company will be prepared for risks which could result from the Y2K millennium change. In September 1999, PSCo and SPS successfully participated in an inter-control center drill involving utilities of the Rocky Mountain Power Area and Southwestern Power Pool respectively, simulating islanding and restoration of generation facilities. The Company has substantially completed all major Y2K initiatives. Based on the results of all testing completed to date, management does not anticipate any significant Y2K related events and, accordingly, does not believe such matters will have a material adverse impact on the financial position, results of operations or cash flows of the Company or its subsidiaries. Employee Matters The Company and its subsidiaries are engaged in certain employment related litigation and intend to contest, or are actively contesting, all such claims, and believe that the ultimate outcome will not have a material adverse impact on the financial position, results of operations or cash flows of the Company or its subsidiaries. 6. Acquisitions and Divestitures (NCE) Acquisition of Planergy Effective April 1, 1998, the Company acquired all of the outstanding common stock of Falcon Seaboard Energy Services, Inc. ("Planergy") and assumed other outstanding debt. Planergy includes Planergy, Inc. and Planergy Services and is primarily engaged in energy consulting, energy efficiency management, conservation programs and mass-market services. Such acquisition was accounted for using the purchase method and the acquired assets and liabilities were valued at their estimated fair market values as of the date of acquisition. 34 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) Planergy has been consolidated as a subsidiary of NC Enterprises in the Company's consolidated financial statements. Sale of Texas-Ohio Gas, Inc. Effective July 1, 1999, the Company sold all of the outstanding common stock of Texas-Ohio Gas, Inc., a gas marketing company, including all retail gas marketing contracts serving customers in the northeast region of the U.S. Certain operations were retained and transferred to e prime and its subsidiaries. This sale did not have a significant impact on the Company's financial position, results of operations or cash flows. 7. Obligated Mandatorily Redeemable Preferred Securities of Subsidiary Trusts Holding Solely Subordinated Debentures (NCE, PSCo and SPS) In May 1998, PSCo Capital Trust I, a wholly-owned trust of PSCo, issued 7,760,000 shares of its 7.60% Trust Originated Preferred Securities for $194 million. The sole asset of the trust is $200 million principal amount of PSCo's 7.60% Deferrable Interest Subordinated Debentures, due June 30, 2038. Holders of the securities are entitled to receive quarterly dividends at an annual rate of 7.60% of the liquidation preference value of $25. The securities are redeemable at the option of PSCo on and after May 11, 2003 at 100% of the principal amount outstanding plus accrued interest. In addition to PSCo's obligations under the Subordinated Debentures, PSCo has agreed, pursuant to a guarantee issued to the trust and the provisions of the trust agreement establishing the trust, on a subordinated basis, payment of distributions on the preferred securities (but not if the trust does not have sufficient funds to pay such distributions) and to pay all of the expenses of the trust (collectively, the "Back-up Undertakings"). Considered together, the Back-up Undertakings constitute a full and unconditional guarantee by PSCo of the trust obligations under the preferred securities. The proceeds from the sale of the 7.60% Trust Originated Preferred Securities were used to redeem all $181.8 million of PSCo's outstanding preferred stock on June 10, 1998, and for general corporate purposes. In October 1996, Southwestern Public Service Capital I, a wholly-owned trust of SPS, issued $100 million of its 7.85% Trust Preferred Securities, Series A. The sole asset of the trust is $103 million principal amount of SPS's 7.85% Deferrable Interest Subordinated Debentures, Series A due September 1, 2036. The securities are redeemable at the option of SPS on and after October 21, 2001 at 100% of the principal amount plus accrued interest. In addition to SPS's obligations under the Subordinated Debentures, SPS has agreed, pursuant to a guarantee issued to the trust, the provisions of the trust agreement establishing the trust and a related expense agreement to guarantee, on a subordinated basis, payment of distributions on the preferred securities (but not if the trust does not have sufficient funds to pay such distributions) and to pay all of the expenses of the trust. Considered together, the Back-up Undertakings constitute a full and unconditional guarantee by SPS of the trust obligations under the preferred securities. The proceeds from the sale were used to reduce short-term debt. 8. Business Segment Information (NCE, PSCo and SPS) NCE: NCE has three reportable segments: electric utility, gas utility and international. The electric utility segment consists primarily of the activities of the three regulated operating companies that provide wholesale and retail electric service in the states of Colorado, Texas, New Mexico, Wyoming, Kansas and Oklahoma. The gas utility segment consists primarily of the activities of three regulated operating companies providing retail gas service in the states of Colorado and Wyoming. The international segment consists of equity investments in foreign operations held by NCI since 1997. Revenues from operating segments below the quantitative thresholds are included in the all other category. Those primarily include a company involved in non-regulated power and gas marketing activities throughout the United States; a company that invests in and develops cogeneration and energy related projects; a company that is engaged in engineering, design construction management and other 35 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) miscellaneous services and a company engaged in energy consulting, energy efficiency management, conservation programs and mass market services. The accounting policies of the segments are the same as those described in Note 1. Summary of Significant Accounting Policies. NCE evaluates performance by each legal entity based on profit or loss generated from the product or service provided. NCE segment information is as follows (in thousands):
Eliminations/ Three months ended: Electric Gas All Unallocated Consolidated September 30, 1999 Utility Utility International Other Amounts * Total -------- ------- ------------- ------ --------- ----- Revenues: External customers $ 701,597 $83,504 $ - $27,786 $ - $812,887 Intersegment 111 1,347 - 41,126 (42,584) - Segment profit 89,210 (3,638) 7,974 6,921 (2,540) 97,927 September 30, 1998 Revenues: External customers $ 759,926 $75,871 $ - $37,087 $ - $872,884 Intersegment 221 1,171 - 25,986 (27,378) - Segment profit 86,731 (6,869) 16,321 4,389 (9,800) 90,772 Nine months ended: September 30, 1999 Revenues: External customers $1,903,181 $487,018 $ - $138,217 $ - $2,528,416 Intersegment 373 5,005 - 91,120 (96,498) - Segment profit 207,338 13,465 26,049 10,299 (8,689) 248,462 September 30, 1998 Revenues: External customers $1,987,033 $483,580 $ - $149,247 $ - $2,619,860 Intersegment 835 3,521 - 56,489 (60,845) - Segment profit 217,004 16,748 13,161 18,458 (31,857) 233,514
* Certain financing costs have been allocated to the operating segments in 1999. PSCo: PSCo has two reportable segments: electric utility and gas utility. During 1998, PSCo had three reportable segments: electric, gas and international. The electric utility segment consists primarily of the activities of PSCo's regulated operations that provide wholesale and retail electric service in the state of Colorado. The gas utility segment consists primarily of the activities of PSCo's regulated gas operations in Colorado. Revenues from operating segments below the quantitative thresholds are included in the all other category. Those segments primarily include a real estate company which owns certain real estate interests of PSCo, a company which owns and manages permanent life insurance policies on certain past and present employees and a finance company that finances certain of PSCo's current assets. The International segment does not apply to PSCo in 1999, as PSCo sold NCI to NC Enterprises effective March 31, 1998, (see Note 3. Investment in Yorkshire Power). 36 NOTES TO CONSOLIDATED CONDENSED FINANCIAL STATEMENTS - (Continued) The accounting policies of the segments are the same as those described in Note 1. Summary of Significant Accounting Policies. PSCo evaluates performance by each legal entity based on profit or loss generated from the product or service provided. PSCo segment information is as follows (in thousands):
Eliminations/ Three months ended: Electric Gas All Unallocated Consolidated September 30, 1999 Utility Utility International Other Amounts * Total -------- ------- ------------- ------ --------- ----- Revenues from external customers $ 400,892 $ 82,471 $ - $ 837 $ - $ 484,200 Segment profit 49,092 (3,579) - 4,236 - 49,749 September 30, 1998 Revenues from external customers $ 466,221 $ 74,635 $ - $ 745 $ - $ 541,601 Segment profit 50,908 (7,152) - 6,095 (5,836) 44,015 Nine months ended: September 30, 1999 Revenues from external customers $1,155,904 $477,537 $ - $ 5,794 $ - $1,639,235 Segment profit 122,483 13,202 - 14,823 - 150,508 September 30, 1998 Revenues from external customers $1,211,607 $473,288 $ - $ 5,946 $ - $1,690,841 Segment profit 128,812 16,077 2,799 13,407 (22,607) 138,488
* Certain financing costs have been allocated to the operating segments in 1999. SPS: SPS operates in the regulated electric utility industry providing wholesale and retail electric service in the states of Texas, New Mexico, Kansas and Oklahoma. Revenues from external customers for this reportable segment were $290.6 million and $284.6 million for the three months ended September 30, 1999 and 1998, respectively. Revenues from external customers for this reportable segment were $717.3 million and $748.4 million for the nine months ended September 30, 1999 and 1998, respectively. 9. Management's Representations (NCE, PSCo and SPS) In the opinion of the registrants, the accompanying unaudited consolidated condensed financial statements for NCE, PSCo and SPS include all adjustments necessary for the fair presentation of the financial position of the Company and its subsidiaries at September 30, 1999 and December 31, 1998 and the results of operations for the three and nine months ended September 30, 1999 and 1998 and cash flows for the nine months ended September 30, 1999 and 1998. The unaudited consolidated condensed financial information and notes thereto should be read in conjunction with the consolidated financial statements and notes included in the combined 1998 Form 10-K for NCE, PSCo and SPS. Because of seasonal and other factors, the results of operations for the three and nine months ended September 30, 1999 should not be taken as an indication of earnings for all or part of the balance of the year. 37 REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS TO NEW CENTURY ENERGIES, INC.: We have reviewed the accompanying consolidated condensed balance sheet of New Century Energies, Inc. (a Delaware corporation) and subsidiaries as of September 30, 1999, and the related consolidated condensed statements of income and shareholders' equity for the three and nine-month periods ended September 30, 1999 and 1998 and the consolidated condensed statements of cash flows for the nine-month periods ended September 30, 1999 and 1998. These financial statements are the responsibility of the Company's management. We conducted our review in accordance with standards established by the American Institute of Certified Public Accountants. A review of interim financial information consists principally of applying analytical procedures to financial data and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with generally accepted auditing standards, 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 review, we are not aware of any material modifications that should be made to the financial statements referred to above for them to be in conformity with generally accepted accounting principles. We have previously audited, in accordance with generally accepted auditing standards, the consolidated balance sheet of New Century Energies, Inc. and subsidiaries as of December 31, 1998, and the related consolidated statements of income, shareholders' equity and cash flows for the year then ended (not presented separately herein), and in our report dated February 23, 1999, we expressed an unqualified opinion on these financial statements. In our opinion, the information set forth in the accompanying consolidated condensed balance sheet as of December 31, 1998, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived. ARTHUR ANDERSEN LLP Denver, Colorado, November 9, 1999 38 REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS TO PUBLIC SERVICE COMPANY OF COLORADO: We have reviewed the accompanying consolidated condensed balance sheet of Public Service Company of Colorado (a Colorado corporation) and subsidiaries as of September 30, 1999, and the related consolidated condensed statements of income for the three and nine-month periods ended September 30, 1999 and 1998 and the consolidated condensed statements of cash flows for the nine-month periods ended September 30, 1999 and 1998. These financial statements are the responsibility of the Company's management. We conducted our review in accordance with standards established by the American Institute of Certified Public Accountants. A review of interim financial information consists principally of applying analytical procedures to financial data and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with generally accepted auditing standards, 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 review, we are not aware of any material modifications that should be made to the financial statements referred to above for them to be in conformity with generally accepted accounting principles. We have previously audited, in accordance with generally accepted auditing standards, the consolidated balance sheet of Public Service Company of Colorado and subsidiaries as of December 31, 1998, and the related consolidated statements of income, shareholder's equity and cash flows for the year then ended (not presented separately herein), and in our report dated February 23, 1999, we expressed an unqualified opinion on these financial statements. In our opinion, the information set forth in the accompanying consolidated condensed balance sheet as of December 31, 1998, is fairly stated, in all material respects, in relation to the consolidated balance sheet from which it has been derived. ARTHUR ANDERSEN LLP Denver, Colorado, November 9, 1999 39 REPORT OF INDEPENDENT PUBLIC ACCOUNTANTS TO SOUTHWESTERN PUBLIC SERVICE COMPANY: We have reviewed the accompanying condensed balance sheet of Southwestern Public Service Company (a New Mexico corporation) as of September 30, 1999, and the related condensed statements of income for the three and nine-month periods ended September 30, 1999 and 1998 and the condensed statements of cash flows for the nine-month periods ended September 30, 1999 and 1998. These financial statements are the responsibility of the Company's management. We conducted our review in accordance with standards established by the American Institute of Certified Public Accountants. A review of interim financial information consists principally of applying analytical procedures to financial data and making inquiries of persons responsible for financial and accounting matters. It is substantially less in scope than an audit conducted in accordance with generally accepted auditing standards, 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 review, we are not aware of any material modifications that should be made to the financial statements referred to above for them to be in conformity with generally accepted accounting principles. We have previously audited, in accordance with generally accepted auditing standards, the balance sheet of Southwestern Public Service Company as of December 31, 1998, and the related statements of income, shareholder's equity and cash flows for the year then ended (not presented separately herein), and in our report dated February 23, 1999, we expressed an unqualified opinion on these financial statements. In our opinion, the information set forth in the accompanying condensed balance sheet as of December 31, 1998, is fairly stated, in all material respects, in relation to the balance sheet from which it has been derived. ARTHUR ANDERSEN LLP Denver, Colorado, November 9, 1999 40 Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations (NCE, PSCo and SPS) NCE's Management's Discussion and Analysis of Financial Condition and Results of Operations Three Months Ended September 30, 1999 Compared to the Three Months Ended September 30, 1998 NCE/NSP Merger On March 24, 1999, the Company and NSP entered into an Agreement and Plan of Merger providing for a strategic business combination of the companies. Consummation of this "merger of equals" is subject to certain closing conditions and the obtaining of applicable regulatory approvals. Assuming all regulatory approvals can be achieved in a timely manner, it is expected the NCE/NSP Merger will be completed in the later half of 2000. At the special shareholder meetings on June 28, 1999, the shareholders of NCE and NSP approved the Agreement and Plan of Merger. The name of the merged company will be Xcel Energy Inc. The combined company is anticipated to be one of the top 10 largest gas and electric energy companies in the U.S. Xcel Energy Inc. will serve approximately 3 million electricity customers and 1.5 million natural gas customers in portions of twelve states. See Note 2. Proposed Merger with Northern States Power Company in Item 1. FINANCIAL STATEMENTS. Earnings Earnings per share (basic and diluted) were $0.85 for the third quarter of 1999 as compared to $0.82 per share (basic and diluted) for the third quarter of 1998. The increase in earnings was primarily attributed to higher retail electric and gas sales resulting from continuing customer growth in Colorado and lower operating and maintenance expenses in the Company's regulated businesses. Electric customer growth was approximately 2.0% over the prior year, with growth in natural gas customers of approximately 3.4%. Electric Operations The following table details the change in electric operating revenues and energy costs for the third quarter of 1999 as compared to the same period in 1998 (thousands of dollars). Increase (Decrease) ------------------- Electric operating revenues: Retail................................................ $(18,085) Wholesale............................................. (92,620) Other (including unbilled revenues)................... 52,068 ------- Total revenues...................................... (58,637) Fuel used in generation............................... (9,844) Purchased power....................................... (59,523) ------- Net increase in electric margin..................... $ 10,730 ======== The following table compares electric Kwh sales by major customer classes for the third quarter of 1999 and 1998. Millions of Kwh Sales 1999 1998 % Change * ---- ---- ---------- Residential................................ 2,947 2,885 2.2% Commercial and industrial.................. 7,654 7,572 1.1 Public authority........................... 203 247 (17.8) ----- ----- Total retail............................. 10,804 10,704 0.9 Wholesale.................................. 4,247 5,189 (18.2) ----- ----- Total.................................... 15,051 15,893 (5.3) ====== ====== Power marketing and trading................ 3,067 666 ** ===== ===== * Percentages are calculated using unrounded amounts ** Percentage change is significant, but presentation of the amount is not meaningful. 41 Electric margin increased $10.7 million or approximately 3.0% in the third quarter of 1999, when compared to the third quarter of 1998, primarily due to slightly higher retail sales resulting from customer growth. This increase was offset, in part, by an increase in PSCo's provisions for estimated customer refunds in connection with the earnings sharing in excess of 11% return on equity. Retail revenues decreased overall despite the higher sales due to lower fuel cost recovery. Wholesale revenues decreased due to lower non-firm sales in 1999. Power trading activities have increased, although revenues and purchased energy costs for these activities are presented net for financial reporting purposes. The electric margin on power trading activities is not significant. The Company's regulated subsidiaries have cost adjustment mechanisms which recognize the majority of the effects of changes in fuel used in generation and purchased power costs and allow recovery of such costs on a timely basis (see Note 4. Regulatory Matters in Item 1. FINANCIAL Statements). PSCo has an ICA, which allows for a 50%/50% sharing of certain fuel and energy cost increases and decreases among customers and shareholders. PSCo recognized cost increases associated with the ICA of approximately $5.6 million during the third quarter 1999, compared to the prior year. Fuel used in generation expense decreased $9.8 million during the third quarter of 1999, as compared to the same quarter in 1998, due primarily to reduced generation and lower coal costs at SPS. This decrease in coal costs is primarily due to negotiations with a new supplier in mid-1998 and lower transportation costs. Purchased power expense decreased $59.5 million during the third quarter of 1999, as compared to the same quarter in 1998, primarily due to a lower volume of non-firm purchases related to wholesale marketing. Gas Operations The following table details the change in gas revenues and gas purchased for resale for the third quarter of 1999 as compared to the same period in 1998 (thousands of dollars). Increase (Decrease) ------------------- Revenues from gas sales (including unbilled revenues). $(9,200) Gas purchased for resale.............................. (12,474) ------- Net increase in gas sales margin..................... 3,274 Transportation revenues............................... 763 ------- Increase in net gas margin........................... $ 4,037 ======= The following table compares gas Dth deliveries by major customer classes for the third quarter of 1999 and 1998. Millions of Dth Deliveries 1999 1998 % Change * ---- ---- ---------- Residential................................ 7.3 6.6 11.2% Commercial................................. 4.1 4.1 0.4 ----- ----- Total sales.............................. 11.4 10.7 7.1 Transportation............................. 28.1 25.8 8.8 ----- ----- Total.................................... 39.5 36.5 8.3 ===== ===== Non-regulated gas marketing and trading.... 61.5 16.4 ** ===== ===== * Percentages are calculated using unrounded amounts ** Percentage change is significant, but presentation of the amount is not meaningful Gas sales margin increased during the third quarter of 1999, when compared to the third quarter of 1998, primarily due to higher retail sales at PSCo resulting from customer growth of approximately 3.4% and higher gas rates effective July 1, 1999, resulting from PSCo's 1998 rate case (approximately $1.3 million). Although 42 non-regulated gas marketing and trading sales increased significantly, the margin on such sales decreased slightly when compared to the prior year. Gas transportation revenues increased approximately $0.8 million during the third quarter of 1999, when compared to the third quarter of 1998, primarily due to higher deliveries at PSCo. PSCo and Cheyenne have in place GCA mechanisms for natural gas sales, which recognizes the majority of the effects of changes in the cost of gas purchased for resale and adjusts revenues to reflect such changes in cost on a timely basis. As a result, the changes in revenues associated with these mechanisms during the third quarter of 1999, as compared to the third quarter of 1998, had little impact on net income. However, the fluctuations in gas sales impact the amount of gas the Company's gas utilities must purchase and, therefore, along with the increases and decreases in the per-unit cost of gas, affect total gas purchased for resale. Other Operating Revenues and Equity in Earnings of Unconsolidated Subsidiaries Other operating revenues increased approximately $7.1 million primarily due to an increase in revenue from energy management and consulting services. Corresponding increases in other operating and maintenance expenses-nonregulated resulted from these activities. Equity earnings from Yorkshire Power decreased $6.6 million over 1998 primarily due to lower operating earnings in 1999 which were impacted by the removal of "pass through" energy cost recovery mechanisms, higher per unit energy costs in the summer months with lower sales and continued competition for customers (see Note 3. Investment in Yorkshire Power in Item 1. FINANCIAL STATEMENTS). Non-Fuel Operating Expenses and Other Income and Deductions Other operating and maintenance expense-regulated decreased $10.5 million from the continued deployment of cost saving-programs instituted as part of the PSCo/SPS Merger. Other operating and maintenance expense-non-regulated increased $3.0 million primarily due to increased costs in providing energy management and consulting services. Depreciation and amortization expense increased $5.3 million primarily due to higher depreciation expense from property additions. Taxes other than income taxes decreased approximately $3.1 million due to a $7.0 million refund of business and personal property taxes in Colorado offset, in part, by higher utility property tax accruals resulting from an increase in plant investment and higher valuation rates. Income taxes increased $7.8 million during the third quarter of 1999, when compared to the same quarter in 1998, primarily due to higher pre-tax income. Nine Months Ended September 30, 1999 Compared to the Nine Months Ended September 30, 1998 Earnings Earnings per share (basic and diluted) were $2.16 for the first nine months of 1999 as compared to $2.10 per share (basic and diluted) for the first nine months of 1998. The increase in earnings were primarily attributed to a higher electric margin resulting from customer growth and an increased contribution from the Company's investment in Yorkshire Power. 43 Electric Operations The following table details the change in electric operating revenues and energy costs for the first nine months of 1999 as compared to the same period in 1998 (thousands of dollars). Increase (Decrease) ------------------- Electric operating revenues: Retail................................................ $ (39,608) Wholesale............................................. (110,081) Other (including unbilled revenues)................... 65,202 ------- Total revenues...................................... (84,487) Fuel used in generation............................... (35,337) Purchased power....................................... (72,606) ------- Net increase in electric margin..................... $23,456 ======= The following table compares electric Kwh sales by major customer classes for the first nine months of 1999 and 1998. Millions of Kwh Sales 1999 1998 % Change * ---- ---- ---------- Residential................................ 7,903 7,781 1.6% Commercial and Industrial.................. 20,991 20,849 0.7 Public Authority........................... 587 625 (6.0) ----- ----- Total Retail............................. 29,481 29,255 0.8 Wholesale.................................. 10,033 11,623 (13.7) ------ ------ Total...................................... 39,514 40,878 (3.3) ====== ====== Power marketing and trading................ 7,500 2,269 ** ===== ===== * Percentages are calculated using unrounded amounts ** Percentage change is significant, but presentation of the amount is not meaningful. Electric margin increased $23.5 million or approximately 2.3% in the first nine months of 1999, when compared to the first nine months of 1998, due to higher retail sales resulting primarily from overall customer growth of approximately 2.0%. Retail revenues decreased despite the slight increase in sales due to lower revenues related to the recovery of fuel costs. Wholesale revenues decreased due to lower non-firm sales, but the margin on such sales is minimal. Electric sales growth for 1999 was negatively impacted by mild spring and early summer weather. Electric sales for 1998 were favorably impacted by hot summer weather. Comparison of retail revenues was also impacted by an SPS 1985 FERC rate case settlement which increased margin approximately $7.7 million in 1998 and an increase in PSCo's provisions for estimated customer refunds in connection with the earnings sharing in excess of 11% return on equity (approximately $4.0 million) during 1999. Fuel used in generation expense decreased $35.3 million during the first nine months of 1999, as compared to 1998, primarily due to reduced generation levels at SPS and lower coal and gas costs at SPS. The lower coal costs are due to a reduction in transportation costs, while the decrease in gas costs is attributable to lower per-unit gas prices. Purchased power expense decreased $72.6 million during the first nine months of 1999, as compared to 1998, primarily due to a lower volume of non-firm purchases related to wholesale marketing activities. This decrease was partially offset by an increase in purchased power expense at SPS resulting from an increase in quantity of power purchased and higher capacity charges. 44 Gas Operations The following table details the change in gas revenues and gas purchased for resale for the first nine months of 1999 as compared to the same period in 1998 (thousands of dollars). Increase (Decrease) ------------------- Revenues from gas sales (including unbilled revenues). $(10,682) Gas purchased for resale.............................. (8,149) -------- Net decrease in gas sales margin..................... (2,533) Transportation revenues............................... 2,769 -------- Increase in net gas margin........................... $ 236 ======== The following table compares gas Dth deliveries by major customer classes for the first nine months of 1999 and 1998. Millions of Dth Deliveries 1999 1998 % Change * ---- ---- ---------- Residential................................ 65.4 65.2 0.5% Commercial................................. 31.5 32.8 (4.0) ----- ----- Total Sales.............................. 96.9 98.0 (1.0) Transportation............................. 85.0 80.6 5.4 ----- ----- Total.................................... 181.9 178.6 1.9 ===== ===== Non-regulated gas marketing and trading ... 141.6 48.2 ** ===== ===== * Percentages are calculated using unrounded amounts ** Percentage change is significant, but presentation of the amount is not meaningful Gas sales margin decreased $2.5 million during the first nine months of 1999, when compared to the first nine months of 1998. Lower retail sales at PSCo resulted from the effects of mild winter weather in 1999, despite a 3.4% increase in customers and an increase in PSCo's gas rates, effective July 1, 1999 due from the 1998 gas rate case. Although non-regulated gas marketing and trading sales increased significantly, the margin on such sales decreased slightly when compared to the prior year. Gas transportation revenues increased approximately $2.8 million during the first nine months of 1999, when compared with the same period in 1998, primarily due to higher deliveries at PSCo. The increase in transport deliveries continues to be impacted by the shifting of various commercial customers to transport customers. Other Operating Revenues and Equity in Earnings of Unconsolidated Subsidiaries Other operating revenues increased slightly during 1999, when compared to the prior year. An increase in revenue from energy management and consulting services was offset, in part, by lower development fee income from non-regulated independent power projects. Equity in earnings of Yorkshire Power and other unconsolidated subsidiaries increased $8.8 million primarily due to higher earnings from Yorkshire Power. NCI's equity in earnings of Yorkshire Power increased by approximately $12 million for the first nine months of 1999, when compared to the same period in 1998, primarily due to Yorkshire Power's 1998 recognition of an impairment of its investment in a U.K. telecommunications company offset, in part, by an unrelated tax adjustment. The net effect of these items reduced 1998 earnings approximately $16.6 million. Additionally, equity losses from independent power projects reduced earnings during 1999. 45 Miscellaneous income and deductions-net decreased primarily due to delay damage penalties incurred in development of certain independent power projects by non-regulated subsidiaries. Non-Fuel Operating Expenses and Other Income and Deductions Other operating and maintenance expense-regulated decreased $12.8 million from the continued deployment of cost saving-programs instituted as part of the PSCo/SPS Merger. Other operating and maintenance expense-nonregulated increased $10.1 million primarily due to increased operating cost due to the acquisition of Planergy, effective April 1, 1998 and higher costs incurred in providing energy management and consulting services. Depreciation and amortization expense increased $15.2 million primarily due to higher depreciation expense from property additions. Taxes other than income taxes increased approximately $6.1 million due to higher utility property tax accruals as a result of an increase in plant investment and higher valuation rates offset, in part, by a $7.0 million refund of business and personal property taxes in Colorado. Interest charges and preferred dividends of subsidiaries increased $6.7 million during 1999 as compared with the same period in 1998. The increase is primarily attributable to higher average amounts of debt outstanding used to finance capital expenditures. Additionally, in May 1998, PSCo issued $194 million of Trust Preferred Originated Preferred Securities. The proceeds were used to redeem all of PSCo's outstanding preferred stock (totaling $181.8 million) in June 1998 (see Note 7. PSCo Obligated Mandatorily Redeemable Preferred Securities of Subsidiary Trust Holding Solely Subordinated Debentures in Item 1. FINANCIAL STATEMENTS). Income taxes declined $11.0 million during the first nine months of 1999, when compared to the same quarter in 1998, primarily due to lower pre-tax income (before equity earnings of Yorkshire Power), the recognition of additional Colorado state tax credits and the recognition of the favorable tax impact of certain prior year PSCo severance costs that were previously recognized as non-deductible. Other Market Risks NCE and its subsidiaries are exposed to market risks, including changes in commodity prices, interest rates and currency exchange rates as fully disclosed in the NCE, PSCo and SPS 1998 Annual Report on Form 10-K. NCE's regulated subsidiaries have limited exposure to commodity price and interest rate risk due to cost-based rate regulation. Exposure to currency exchange risk is related to NCE's investment in Yorkshire Power (see Note 3. Investment in Yorkshire Power in Item 1. FINANCIAL STATEMENTS). There have been no material changes in the market risk exposures that affect the quantitative and qualitative disclosures presented as of December 31, 1998 in the 1998 Annual Report on Form 10-K. Commitments and Contingencies Year 2000 Issue The Y2K issue is a result of a universal programming standard that records dates as six digits, e.g., mm/dd/yy, using only the last two digits for the year. Any automated system software or firmware that uses two-digit fields could understand the year 2000 as the year 1900 if the issue is not corrected. This situation is not limited to computers; it has the potential to affect many systems, components and devices, which have embedded computer chips, which may be date sensitive. The Y2K issue could result in a major system failure or miscalculations and does impact many NCE systems considered critical or important to the Company's business operations. Systems posing the greatest business risks to the Company include power generation and distribution systems, telecommunications systems, energy trading systems and billing systems. The Company is correcting all 46 potential Y2K failure points identified in its critical automated systems to maintain service to its customers and to mitigate legal and financial risks. In 1997, the Company established the Y2K Program Office to oversee all corporate-wide Y2K initiatives. These initiatives encompass all computer software, embedded systems, as well as contingency planning. Teams of internal and external specialists were established to inventory and assess and test critical computer programs and automated operational systems and modify those that may not be Y2K compliant. The inventory and assessment phases for information technology ("IT") systems were completed in 1998. Remediation and testing phases for all critical IT systems were completed by June 30, 1999. For critical non-IT systems, which exist primarily in the generation, transmission and distribution areas of the business, the inventory, assessment, remediation and testing phases were also completed by June 30, 1999. NCE has achieved "Y2K Ready" status for all mission-critical electrical generating and transmission facilities. Readiness was accomplished by June 30, 1999, in accordance with the guidelines established by the North American Electric Reliability Council ("NERC"). NCE is a participant in the NERC Y2K Program that has established reporting criteria and milestone dates for electric utilities. The final step of this program was the submittal of a letter to the president of NERC, certifying that the company has met the NERC Y2K goal. NCE submitted its Y2K certification letter, without exceptions, with its June 1999 NERC report. In October 1999, NCE successfully completed an external review of NCE's Y2K program by an independent third party. The review criteria followed by the external review team were developed for the independent verification and validation study that NERC is conducting for the DOE. The Company has identified third parties, with which it has material business relationships including interconnected utilities, telecommunications service providers, fuel and water suppliers, equipment suppliers, leased facilities and financial institutions. Subject matter experts, along with functional managers, continue to evaluate the current list of third parties and have ongoing discussions with these and other critical suppliers about their Y2K readiness and contingency planning efforts. The Company currently expects to incur costs of approximately $17 million (approximately $13 million has been spent through September 30, 1999) in operating and capital expenditures to modify its computer software, hardware and other automated systems used in operations enabling proper data processing relating to the year 2000 and beyond. The Company has spent approximately $18 million in operating and capital expenditures for the accelerated replacement of certain non-compliant IT systems. PSCo and SPS have incurred the majority of these costs. The table below details the actual costs incurred during 1998 and prior periods; the actual costs incurred through the nine months ended September 30, 1999; and the estimated costs to be incurred during the remainder of 1999 and the first quarter of 2000. A significant portion of the remaining costs to be incurred consists of finalizing remaining work on nonmission-critical systems, testing, project management and contingency planning. Actual Remaining Estimated Actual Costs Costs Estimated Costs Total Project 1998 and Prior 1999 to be Incurred Costs -------------- ---- -------------- ----- (in millions) Operating expenses.. $8.0 $3.9 $3.0 $14.9 Capital for automated system components 0.7 0.6 0.3 1.6 IT replacement projects: Operating...... 0.2 0.6 0.1 0.9 Capital........ 6.4 10.9 - 17.3 ---- ---- ---- ----- Total........ $15.3 $16.0 $3.4 $34.7 ===== ===== ==== ===== Yorkshire Power has also undertaken activities to address Y2K issues. The estimated proportionate share of Yorkshire's incremental Y2K costs (costs which would not have been required in the normal course of 47 business) that will flow through to the Company's earnings as a result of such activities is not expected to have a material impact on the financial condition or results of operations of the Company. The most reasonably likely worst case scenario resulting during Y2K critical dates is a loss of production capacity from certain of the Company's generating units, along with loss of a portion of the communication system that is critical to generation and distribution control. If this were to occur, the Company's operating utilities may be required to "island" (separate from neighboring interconnected utilities) their generation and distribution systems in their service territories. As part of this scenario, difficulty could be encountered with the restart of generating units. The overall blackout recovery plan for NCE is designed so that this most reasonably likely worst case scenario would be addressed and electricity restored. Critical components of this plan have been and continue to be tested to provide assurance that the Company will be prepared for risks which could result from the Y2K millennium change. In September 1999, PSCo and SPS successfully participated in an inter-control center drill involving utilities of the Rocky Mountain Power Area and Southwestern Power Pool respectively, simulating islanding and restoration of generation facilities. The Company has substantially completed all major Y2K initiatives. Based on the results of all testing completed to date, management does not anticipate any significant Y2K related events and, accordingly, does not believe such matters will have a material adverse impact on the financial position, results of operations or cash flows of the Company or its subsidiaries. Common Stock Dividend The Board of Directors approved a $0.58 per share dividend payable to shareholders of the Company for the third quarter of 1999 and $1.74 for the year-to-date. The Company's common stock dividend level is dependent upon the Company's financial position, results of operations, cash flows and other factors, including the proposed merger with NSP. The Board of Directors of the Company will continue to evaluate the common stock dividend on a quarterly basis. Liquidity and Capital Resources Cash Flows - Nine Months Ended September 30 1999 1998 Decrease ---- ---- -------- Net cash provided by operating activities (in millions) ............ $361.1 $503.0 $(141.9) Cash provided by operating activities decreased during the first nine months of 1999, when compared to the same period in 1998, primarily due to the cash proceeds, received in 1998 by SPS and a non-regulated subsidiary, of approximately $67 million for the recovery of deferred costs and income from the investment in a non-regulated energy development project and the net changes in the recovery of purchased gas and electric energy costs. 1999 1998 Increase ---- ---- -------- Net cash used in investing activities (in millions) ............ $(462.0) $(419.4) $(42.6) Cash used in investing activities increased during 1999, when compared to 1998, primarily due to an increase in the level of construction expenditures. 1999 1998 Increase ---- ---- -------- Net cash provided by (used in) financing activities (in millions) ........... $84.7 $(85.3) $170.0 Cash provided by financing activities increased during 1999, when compared to 1998, primarily due to higher net proceeds from debt financing activities in 1999. During the first quarter of 1999, PSCo refinanced approximately $48.75 million to take advantage of lower interest rates and SPS issued $100 million of senior notes used initially for the repayment of short-term debt. PSCo issued $200 million of long-term debt in July 1999, the 48 proceeds of which were used for general corporate purposes. During 1998, PSCo issued $250 million of long-term debt in April 1998 which was used to repay short-term and other debt and in May 1998, PSCo issued $194 million of Trust Originated Preferred Securities the proceeds of which were used to redeem all of PSCo's outstanding preferred stock (totaling $181.8 million) on June 10, 1998 (see Note 7. Obligated Mandatorily Redeemable Preferred Securities of Subsidiary Trust Holding Soley Subordinated Debentures in Item 1. FINANCIAL STATEMENTS). Financing Activities Long-Term Debt During the first quarter of 1999, PSCo refinanced a portion of its pollution control bonds in the amount of $48.75 million to take advantage of lower interest rates. The interest rate on the new bonds is 5.1% compared to 5 7/8% on $21.5 million and 7 3/8% on $27.25 million. In addition, SPS issued $100 million of 6.2% unsecured senior notes due March 1, 2009. The proceeds were used initially for the repayment of certain short-term debt, pending the retirement of $90 million of the SPS 6 7/8% First Mortgage Bonds due December 1, 1999 and for other general corporate purposes. On June 29, 1999, PSCo filed a registration statement to issue up to $500 million of unsecured debt. On July 16, 1999, PSCo issued $200 million of unsecured senior notes, at an interest rate of 6 7/8%, due July 15, 2009. Proceeds were used for general corporate purposes including capital expenditures, repayment of short-term debt and refunding of long-term debt on maturity or otherwise. Bank Lines of Credit and Compensating Bank Balances During the second quarter of 1999, PSCo entered into a credit facility, which provides for $300 million in committed lines of credit, replacing an existing $150 million credit facility. The credit facility expires June 23, 2000. During the first quarter of 1999, SPS extended its $200 million committed line of credit until February 25, 2000. On November 1, 1999, the NMPRC approved SPS's request to increase its short-term debt authority by $100 million to $300 million. NCE is currently negotiating a $100 million credit facility. This facility will be in addition to NCE's $225 million credit facility which expires August 11, 2002. Electric Utility Industry Electric utilities have historically operated in a highly regulated environment in which they have an obligation to provide electric service to their customers in return for an exclusive franchise within their service territory with an opportunity to earn a regulated rate of return. This regulatory environment is changing. The generation sector has experienced competition from nonutility power producers and the FERC is requiring utilities, including the Company's subsidiaries, to provide wholesale transmission service to others and may order electric utilities to expand their transmission systems to facilitate transmission services without impairing reliability. State regulatory authorities are in the process of changing utility regulations in response to federal and state statutory changes and evolving markets, including consideration of providing open access to retail customers. All of the Company's jurisdictions continue to study and evaluate utility regulations with respect to competition. Deregulation legislation was passed in Texas and New Mexico during the second quarter of 1999. New Mexico On April 8, 1999, New Mexico enacted the Electric Utility Restructuring Act of 1999, which allows customer choice for residential, small commercial and educational customers beginning January 1, 2001. All remaining customers will be allowed customer choice on January 1, 2002. Customers of a municipal utility and customers of a distribution 49 cooperative utility will be afforded choice only if the respective utility elects to participate. The legislation provides for recovery of no less than 50% of stranded costs quantified by the NMPRC, which has not yet been determined. Transition costs must be approved by the NMPRC prior to being recovered through a non-by-passable wires charge, which must be included in a transition plan filing. All public electric utilities operating in New Mexico must file a transition plan with the NMPRC by March 1, 2000. Before January 1, 2001, SPS must separate its utility operations into at least two segments: a) energy generation services and b) transmission and distribution (including retail operations) services either by the creation of separate affiliates that may be owned by a common holding company or by the sale of assets to one or more third parties. A regulated company will be prohibited from providing unregulated services. Texas On June 18, 1999, an electric utility restructuring act ("SB-7") was passed in Texas, which allows for retail competition, for most areas of the state, beginning January 1, 2002. The legislation requires, among other things, a rate freeze for all customers, effective September 1, 1999 until January 1, 2002 together with an annual earnings test; a 6% rate reduction for those residential and small commercial customers who choose not to switch suppliers at the start of retail competition; the unbundling of business activities, costs and rates relating to generation, transmission and distribution and retail services; reductions in NOx and SO2 emissions and the recovery of stranded costs. The PUCT can delay the date for retail competition if a power region is unable to offer fair competition and reliable service during pilot projects which begin for all utilities on June 1, 2001 for 5% of the utility's combined load of all customer classes. As part of the above Texas legislation, SPS is required to file a separation plan on January 10, 2000, for the unbundling of business activities relating to 1) generation, 2) transmission and distribution and 3) retail services. The plan is to be implemented on January 1, 2002. Also, SPS is required to file a rate case on April 1, 2000 to set the rates for the transmission and distribution services, which are to be unbundled and implemented on January 1, 2002. The Company is evaluating the effect of these filings on SPS. The legislation specifically addresses competition in the Texas Panhandle, where SPS operates, recognizing that certain transmission constraints exist within the region that require full retail customer choice to develop on a more structured schedule than the rest of the state. SPS must file a transition to competition plan with the PUCT by December 1, 2000. SPS, with no estimated stranded costs, must direct any excess earnings indicated in the annual earnings tests during the period January 1, 1999 through December 31, 2001 to improvements in transmission and distribution facilities, to capital expenditures to improve air quality or to accelerate the amortization of regulatory assets (subject to PUCT approval). Additionally, the Texas legislation requires that no generation company can own and control more than 20% of the installed capacity located in or capable of delivering electricity to a power region. Utilities owning more than 400 Mw must auction entitlements to at least 15% of the utility's installed generation capacity used for providing electric services to Texas retail customers. The capacity entitlement auctions are to continue for 5 years or until 40% of the utility's residential and small commercial customers served prior to the start date of competition are served by non-affiliated companies. The legislation includes several possible remedies to market power abuses. These provisions are not immediately applicable to SPS due to the existing transmission constraints and market power issues in the Panhandle region. In connection with the NCE/NSP Merger approval proceedings, the Company filed supplemental testimony with the PUCT in October 1999 outlining its plan to address the various provisions of SB-7. In general, the plan presented by the Company provides for the transfer of ownership or control of 595 Mw of generating capacity (either through capacity entitlement auction or divesting) to other competitors and the addition of transmission lines to import an additional 400 Mw from other geographic regions. The major components of this plan include the following: 50 - - auction entitlements (409 Mw or 15 percent of installed generation capacity) to capacity owned and controlled by SPS, that is dedicated to serving Texas retail customers, by January 1, 2002. The Company would continue to own and operate the capacity, but competitors would have the right to dispatch the power. - - divest 186 Mw of SPS-area generating capacity by January 1, 2002 in order to further reduce market dominance, - - separate SPS existing competitive functions beginning September 1, 2000, - - unbundle SPS into three separate companies beginning January 1, 2002, and - - implement a pilot program for retail access for at least 5 percent of its Texas retail load in June 2001 and to expand the pilot program to 20% of customer load in 2002. Most of the other Texas utilities will be moving to full customer choice in 2002. The SPS plan is designed to address the market power issues related to the deregulation legislation and would promote further competition before the end of 2006 by allowing only competitors to build new plants in the region between now and then, by adding even more transmission lines, and possibly by further divesting some generation. Hearings on the NCE/NSP Merger are scheduled to begin in late February, 2000 and the final order is expected in the second quarter of 2000. Financial Reporting Considerations The Emerging Issues Task Force of the Financial Accounting Standards Board reached a consensus in Issue No. 97-4, "Deregulation of the Pricing of Electricity" ("EITF 97-4") indicating that when deregulatory legislation is passed or when a rate order (whichever is necessary to effect change in the jurisdiction) that contains sufficient detail for an enterprise to reasonably determine how the transition plan will affect the separable portion of its business whose pricing is being deregulated is issued, the enterprise should stop applying SFAS 71 to that separable portion of its business. While legislation has been enacted in Texas and New Mexico, there are several unresolved issues that will significantly impact how and when deregulation related to the generation portion of the business, will be implemented by SPS. It is expected that SPS will discontinue the application of SFAS 71 related to the generation portion of the business when the provisions of EITF 97-4 have been met. Accounting Pronouncements Issued But Not Yet Effective In June 1998, the FASB issued SFAS 133, "Accounting for Derivative Instruments and Hedging Activities." This statement requires companies to record derivatives on the balance sheet as assets and liabilities, measured at fair value. Gains or losses resulting from changes in the values of those derivatives would be accounted for depending on the use of the derivative and whether it qualifies for hedge accounting. In July 1999, the FASB delayed the effective date for one year, to fiscal years beginning after June 15, 2000. The Company is currently evaluating the potential impact of this accounting standard and will adopt the standard as required by January 1, 2001. 51 PSCo's Management's Discussion and Analysis of Financial Condition and Results of Operations Three Months Ended September 30, 1999 Compared to the Three Months Ended September 30, 1998 Earnings Available for Common Stock Earnings were $49.7 million for the third quarter of 1999, as compared to $44.0 million for the third quarter of 1998, primarily due to an increase in electric margin resulting from strong customer growth of 2.6%, an increase in gas margin resulting from customer growth and higher rates, and lower operating and maintenance expenses. Electric Operations The following table details the change in electric operating revenues and energy costs for the three months ended September 30, 1999, as compared to the same period in 1998 (in thousands of dollars). Increase (Decrease) ------------------- Electric operating revenues: Retail....................................... $17,553 Wholesale.................................... (90,727) Other (including unbilled revenues).......... 7,845 ------- Total revenues.............................. (65,329) Fuel used in generation....................... (436) Purchased power............................... (68,848) ------- Net increase in electric margin............. $ 3,955 ======= The following table compares electric Kwh sales by major customer classes for the three months ended September 30, 1999 and 1998. Millions of Kwh Sales 1999 1998 % Change * ---- ---- ---------- Residential ..................... 1,905 1,779 7.1% Commercial and Industrial ....... 4,459 4,278 4.2 Public Authority ................ 54 54 (0.1) ------ ------ Total Retail................... 6,418 6,111 5.0 Wholesale **..................... 1,063 2,389 (55.5) ------ ------ Total............................ 7,481 8,500 (12.0) ====== ====== * Percentages are calculated using unrounded amounts ** Excludes power trading activities Electric margin increased in the third quarter of 1999, when compared to the third quarter of 1998, primarily due to higher retail sales of 5.0% resulting primarily from customer growth of approximately 2.6%. The higher margin was offset, in part, by the negative impact of cost sharing under the ICA (approximately $5.6 million). The ICA is a cost adjustment mechanism that allows for a 50%/50% sharing of certain fuel and energy cost increases and decreases among customers and shareholders. Provisions for estimated customer refunds in connection with the earnings sharing in excess of 11% return on equity increased approximately $2.9 million in 1999 (see Note 4. Regulatory Matters in Item 1. FINANCIAL STATEMENTS). The decrease in the wholesale revenues and sales resulted primarily from lower non-firm sales in 1999, however, overall power trading activities increased in 1999. The revenues and purchased energy costs for such activities are presented net for financial reporting purposes. The electric margin on power trading activities is not significant. 52 Fuel used in generation expense decreased approximately $0.4 million during the third quarter of 1999, as compared to the same quarter in 1998, primarily due to lower generation levels at PSCo's power plants resulting from the milder summer temperatures. Purchased power expense decreased $68.8 million during the third quarter of 1999, as compared to the same quarter in 1998, primarily due to the lower non-firm power purchases offset, in part, by higher firm power purchases under new contracts. Gas Operations The following table details the change in revenues from gas sales and gas purchased for resale for the third quarter of 1999, as compared to the same period in 1998 (in thousands of dollars). Increase (Decrease) ------------------- Revenues from gas sales (including unbilled revenues) $ 7,092 Gas purchased for resale........................ 1,972 ------- Net increase in gas sales margin.............. 5,120 Transportation revenues......................... 744 ------- Increase in net gas margin.................... $ 5,864 ======= The following table compares gas Dth deliveries by major customer classes for the third quarter of 1999 and 1998. Millions of Dth Deliveries 1999 1998 % Change * ---- ---- ---------- Residential................... 6.7 6.4 4.6% Commercial.................... 3.9 3.8 1.6 ----- ----- Total sales................. 10.6 10.2 3.5 Transportation................ 21.0 22.2 (5.7) ----- ----- Total....................... 31.6 32.4 (2.8) ===== ===== * Percentages are calculated using unrounded amounts Gas sales margin increased during the third quarter of 1999, when compared to the third quarter of 1998, primarily due to a 3.5% increase in retail gas sales resulting from customer growth of approximately 3.4%. In addition, gas rates increased, effective July 1, 1999, as a result of the 1998 gas rate case resulting in higher revenues of approximately $1.1 million. Gas transportation revenues increased $0.7 million during the third quarter of 1999, compared to the third quarter of 1998, primarily due to the impact of the 1998 gas rate case, resulting in higher revenues of approximately $0.2 million. PSCo has in place a GCA mechanism for natural gas sales, which recognizes the majority of the effects of changes in the cost of gas purchased for resale and adjusts revenues to reflect such changes in costs on a timely basis. As a result, the changes in revenues associated with these mechanisms during the third quarter of 1999, as compared to the third quarter of 1998, had little impact on net income. However, the fluctuations in gas sales impacts the amount of gas PSCo must purchase and, therefore, along with the increases and decreases in the per-unit cost of gas, affect total gas purchased for resale. Non-Fuel Operating Expenses and Other Income and Deductions Other operating and maintenance expenses decreased approximately $6.4 million primarily due to lower administrative and general costs, including a decrease in pension costs. 53 Depreciation and amortization increased $5.0 million during the third quarter of 1999, as compared to the third quarter of 1998, primarily due to the depreciation of property additions. Taxes other than income taxes decreased approximately $3.8 million during the third quarter of 1999, as compared to the third quarter of 1998, primarily due to a $7 million refund of business and personal property tax in Colorado offset, in part, by higher property tax accruals resulting from an increase in plant investment and higher valuation rates. Income taxes increased approximately $1.4 million during the third quarter of 1999, as compared to the third quarter of 1998, primarily due to higher pre-tax income, despite the recognition of additional Colorado state tax credits. Other income and deductions decreased $3.4 million during the third quarter of 1999, as compared to the third quarter of 1998, primarily due to higher non-utility operating expenses attributed to affiliate billings and customer rebates. Interest charges increased approximately $4.6 million during the third quarter of 1999, as compared to the third quarter of 1998. The increase is primarily attributable to costs to finance capital expenditures, including higher interest costs on short-term debt. Additionally, in July 1999, PSCo issued $200 million of 6 7/8% Series A Senior Notes, due in July 2009. Nine Months Ended September 30, 1999 Compared to the Nine Months Ended September 30, 1998 Earnings Available for Common Stock Earnings were $150.5 million for the first nine months of 1999, as compared to $138.5 million for the first nine months of 1998. The significant increase is primarily attributed to an increase in electric margin resulting from customer growth of 2.6% and lower operating and maintenance expense offset, in part, by higher interest costs. Electric Operations The following table details the change in electric operating revenues and energy costs for the nine months ended September 30, 1999, as compared to the same period in 1998 (in thousands of dollars). Increase (Decrease) ------------------- Electric operating revenues: Retail....................................... $27,683 Wholesale.................................... (92,253) Other (including unbilled revenues).......... 8,867 ------- Total revenues.............................. (55,703) Fuel used in generation....................... 6,128 Purchased power............................... (90,589) ------- Net increase in electric margin............. $28,758 ======= 54 The following table compares electric Kwh sales by major customer classes for the nine months ended September 30, 1999 and 1998. Millions of Kwh Sales 1999 1998 % Change * ---- ---- ---------- Residential ..................... 5,403 5,135 5.2% Commercial and Industrial ....... 12,180 11,754 3.6 Public Authority ................ 162 140 15.2 ------ ------ Total Retail................... 17,745 17,029 4.2 Wholesale **..................... 3,530 5,291 (33.3) ------ ------ Total............................ 21,275 22,320 (4.7) ====== ====== * Percentages are calculated using unrounded amounts ** Excludes power trading activities Electric margin increased $28.8 million or approximately 4.6% during the first nine months of 1999, when compared to the same period in 1998, primarily due to higher retail sales of 4.2% resulting primarily from customer growth of approximately 2.6% and increased usage by existing customers. Provisions for estimated customer refunds in connection with the earnings sharing in excess of 11% return on equity were $11.3 million in 1999 compared to $7.3 million in 1998 (see Note 4. Regulatory Matters in Item 1. FINANCIAL STATEMENTS). The decrease in the wholesale revenues and sales resulted primarily from lower non-firm sales in 1999, however, power trading activities increased in 1999. The revenues and purchased energy costs for such activities are presented net for financial reporting purposes. The electric margin on power trading activities is not significant. Fuel used in generation expense increased approximately $6.1 million during the first nine months of 1999, as compared to the same period in 1998, primarily due to increased generation levels at PSCo's power plants to serve retail customers. Purchased power expense decreased $90.6 million during the first nine months of 1999, as compared to the same period in 1998, primarily due to the lower non-firm power purchases offset, in part, by higher firm power purchases under new contracts. Gas Operations The following table details the change in revenues from gas sales and gas purchased for resale for the first nine months of 1999, as compared to the same period in 1998 (in thousands of dollars). Increase (Decrease) ------------------- Revenues from gas sales (including unbilled revenues) $ 1,468 Gas purchased for resale........................ 1,994 ------- Net decrease in gas sales margin.............. (526) Transportation revenues......................... 2,781 ------- Increase in net gas margin.................... $ 2,255 ======= The following table compares gas Dth deliveries by major customer classes for the first nine months of 1999 and 1998. Millions of Dth Deliveries 1999 1998 % Change * ---- ---- ---------- Residential................... 63.5 63.3 0.4% Commercial.................... 29.8 31.1 (4.3) ------- -------- Total sales................. 93.3 94.4 (1.1) Transportation................ 71.1 68.3 4.2 ------- -------- Total....................... 164.4 162.7 1.1 ======= ======== * Percentages are calculated using unrounded amounts 55 Gas sales margin decreased slightly during the first nine months of 1999, when compared to the same period in 1998, primarily due to a 1.1% decrease in retail gas sales resulting from milder winter weather, with temperatures approximately 2% warmer than the prior year. Gas transportation revenues increased $2.8 million during the first nine months of 1999, compared to the same period in 1998, primarily due to higher deliveries. The increase in transport deliveries continues to be impacted by the shifting of various commercial customers to transport customers. PSCo has in place a GCA mechanism for natural gas sales, which recognizes the majority of the effects of changes in the cost of gas purchased for resale and adjusts revenues to reflect such changes in costs on a timely basis. As a result, the changes in revenues associated with these mechanisms during the nine months ended September 30, 1999, as compared to the same period in 1998, had little impact on net income. However, the fluctuations in gas sales impacts the amount of gas PSCo must purchase and, therefore, along with the increases and decreases in the per-unit cost of gas, affect total gas purchased for resale. The decrease in the quantity of gas purchased in 1999 lowered costs, but was offset by the recovery of costs previously deferred through the GCA. Non-Fuel Operating Expenses and Other Income and Deductions Other operating and maintenance expenses decreased approximately $6.4 million primarily due to lower administrative and general costs, including a decrease in pension costs. Depreciation and amortization increased $12.7 million during the first nine months of 1999, as compared to the same period in 1998, primarily due to the depreciation of property additions. Income taxes decreased approximately $5.0 million during the first nine months of 1999, as compared to the same period in 1998, primarily due to the recognition of additional Colorado state tax credits and the recognition of the favorable tax impact of deducting certain prior year severance costs that were previously recognized as non-deductible. Other income and deductions decreased $6.7 million during the first nine months of 1999, as compared to the first nine months of 1998. On March 31, 1998, NCI and its subsidiaries were transferred through the sale by PSCo of all the outstanding common stock of NCI at net book value (approximately $292.6 million), to NC Enterprises, an intermediate holding company of NCE, and received as consideration a promissory note from NC Enterprises (see Note 3. Investment in Yorkshire Power in Item 1. FINANCIAL STATEMENTS). The first nine months of 1999 include approximately $10.1 million of interest income on the promissory note, excluding income taxes, compared to $10.3 million of interest income in 1998 and the recognition of equity earnings associated with PSCo's investment in Yorkshire Power of approximately $3.4 million in the first quarter of 1998, prior to the sale. In addition, other non-utility income decreased $3.1 million. Interest charges and dividend requirements and redemption premiums on preferred stock increased approximately $8.5 million during the first nine months of 1999, as compared to the first nine months of 1998. The increase is primarily attributable to costs to finance capital expenditures, including higher interest costs on long-term debt resulting from the April 1998 issuance of $250 million of long-term debt and July 1999 issuance of $200 million. Additionally, in May 1998, PSCo issued $194 million of Trust Preferred Originated Preferred Securities. The proceeds were used to redeem all of PSCo's outstanding preferred stock (totaling $181.8 million) in June 1998 (see Note 7. Obligated Mandatorily Redeemable Preferred Securities of Subsidiary Trusts Holding Solely Subordinated Debentures in Item 1. FINANCIAL STATEMENTS). 56 Commitments and Contingencies See Note 5. Commitments and Contingencies in Item 1. FINANCIAL STATEMENTS. Financing Activities Discussion relating to PSCo's financing activities is covered under "Financing Activities" in NCE's Management's Discussion and Analysis of Financial Condition and Results of Operations. 57 SPS's Management's Discussion and Analysis of Financial Condition and Results of Operations Three Months Ended September 30, 1999 Compared to the Three Months Ended September 30, 1998 Earnings Available for Common Stock Earnings available for common stock were $42.5 million during the third quarter of 1999 compared to $36.9 million for the same quarter in 1998. Earnings increased primarily due to the effects of higher sales and lower operating and maintenance costs. Operating Revenues Electric Operations Substantially all of SPS's operating revenues result from the sale of electric energy. The principal factors impacting revenues are the amount and price of energy sold. The following table details the change in electric operating revenues and energy costs for the three months ended September 30, 1999, as compared to the same period in 1998 (thousands of dollars). Increase (Decrease) ------------------- Electric operating revenues: Retail.............................. $(36,815) Wholesale........................... (816) Other (including unbilled revenues). 43,570 ------- Total revenues.................... 5,939 Fuel used in generation.............. (8,954) Purchased power...................... 8,073 ------- Net increase in electric margin... $ 6,820 ======== The following table compares electric Kwh sales by major customer classes for the three months ended September 30, 1999 and 1998. Millions of Kwh Sales 1999 1998 % Change* ------- ----- --------- Residential ............ 993 1,060 (6.2)% Commercial and Industrial 3,025 3,133 (3.5) Public Authority ....... 149 192 (22.8) ----- ----- Total Retail.......... 4,167 4,385 (5.0) Wholesale............... 3,184 2,800 13.7 ----- ----- Total................... 7,351 7,185 2.3 ===== ===== * Percentages are calculated using unrounded amounts. Electric operating revenues increased $5.9 million or 2.1% during the third quarter in 1999, when compared to the same period in 1998, primarily due to customer growth and higher unbilled revenue of approximately $9.9 million offset by the effects of lower retail sales of 5%. Although weather in the third quarter of 1999 was slightly above normal, the decrease in Kwh sales resulted from the hot weather occurring in the third quarter of 1998, which served to increase loads in 1998 as compared to the same period in 1999 for air conditioning and irrigation. The decreases in retail and wholesale revenue relates to lower billed revenues for the recovery of fuel costs (approximately $27 million), which was offset by an increase of approximately $30 million in deferred fuel revenue included in other electric operating revenues. Fuel used in generation expense decreased $9.0 million or 6.4% during the third quarter of 1999, when compared to the same period in 1998, primarily due to a 5.8% decrease in generation levels required to serve 58 retail customers and lower coal costs for the quarter offset, in part, by higher gas costs as a result of higher market prices. The decrease in coal costs is primarily due to negotiations with a new supplier in mid-1998 and lower transportation costs. Purchased power increased $8.1 million during the third quarter of 1999, when compared to the same period in 1998, due to an increase in capacity costs of $6.4 million related to new purchase power contracts and an increase in wholesale purchases. SPS generates substantially all of its power for sale to its firm retail and wholesale customers and sells non-firm energy as the market demands. Similarly, SPS will purchase low-cost non-firm energy when available and as needed to meet customer requirements. SPS has fuel cost adjustment mechanisms which recognize the majority of the effects of changes in fuel used in generation and purchased power costs and allow recovery of such costs on a timely basis. As a result, the changes in revenues associated with these mechanisms during the third quarter of 1999, when compared to the third quarter of 1998, had little impact on net income. (See discussion on "SPS Electric Cost Adjustment Mechanisms" Note 4. Regulatory Matters - in Item 1. FINANCIAL STATEMENTS). Non-Fuel Operating Expenses Other operating and maintenance expenses decreased $4.3 million or 12.5% during the third quarter of 1999, as compared to the same period in 1998, primarily due to lower administrative and general expenses and other reductions resulting from the continued deployment of cost saving programs instituted as part of the PSCo/SPS Merger offset, in part, by higher maintenance costs. Income taxes increased $3.3 million during the third quarter of 1999, as compared to the same period in 1998, primarily due to the effect of higher pre-tax income. The effective income tax rates for the quarter ended September 30, 1999 and 1998 were 37.0% and 37.1%, respectively. Interest Charges Interest charges increased $1.0 million during the third quarter of 1999, as compared to the same period in 1998, primarily due to higher long-term debt costs, resulting from the issuance of $100 million of new debt in March 1999. The proceeds from the long-term debt issuance were initially used for the repayment of certain short-term debt, pending the retirement of $90 million in bonds due December 1, 1999, thus lowering other interest expense ($0.7 million). Nine Months Ended September 30, 1999 Compared to the Nine Months Ended September 30, 1998 Earnings Available for Common Stock Earnings available for common stock were $88.8 million during the nine months ended September 30, 1999 compared to $92.0 million for the same period in 1998. Earnings for 1998 were favorably impacted by the hot dry weather and a FERC rate case settlement. 59 Operating Revenues Electric Operations Substantially all of SPS's operating revenues result from the sale of electric energy. The principal factors impacting revenues are the amount and price of energy sold. The following table details the change in electric operating revenues and energy costs for the nine months ended September 30,1999, as compared to the same period in 1998 (thousands of dollars). Increase (Decrease) ------------------- Electric operating revenues: Retail.............................. $(70,027) Wholesale........................... (16,752) Other (including unbilled revenues). 55,646 ------ Total revenues.................... (31,133) Fuel used in generation.............. (40,941) Purchased power...................... 14,862 ------ Net decrease in electric margin... $ (5,054) ======== The following table compares electric Kwh sales by major customer classes for the nine months ended September 30, 1999 and 1998. Millions of Kwh Sales 1999 1998 % Change* -------- ------- --------- Residential ............ 2,339 2,490 (6.1)% Commercial and Industrial 8,322 8,621 (3.5) Public Authority ....... 423 481 (12.2) ----- ----- Total Retail.......... 11,084 11,592 (4.4) Wholesale............... 6,503 6,332 2.7 ----- ----- Total................... 17,587 17,924 (1.9) ====== ====== * Percentages are calculated using unrounded amounts. Electric operating revenues decreased $31.1 million or 4.2% during the nine months ended September 30, 1999, when compared to the same period in 1998, primarily due to lower retail Kwh sales (4.4%), lower revenues related to the recovery of fuel costs (totaling approximately $64 million) and the $7.7 million settlement for a 1985 FERC rate case settlement recorded in 1998. Higher unbilled revenue of $27.7 million and higher deferred fuel revenue of approximately $33 million offset these decreases. The decrease in Kwh sales was primarily the result of the hot dry weather which occurred in the second and third quarters of 1998 serving to increase air conditioning and irrigation loads in 1998 and a decrease in oil well pumping sales in 1999. A portion of the decrease in Kwh sales resulted from a change in the billing cycle of various customers, which is offset by the higher level of unbilled revenues. Fuel used in generation expense decreased $40.9 million or 11.7% during the nine months ended September 30, 1999, when compared to the same period in 1998, primarily due to lower coal and gas costs for the current period and a 4.7% decrease in generation levels required to serve retail customers. The decrease in coal costs is primarily due to negotiations with a new supplier in mid-1998 and lower transportation costs. Cost of natural gas used in generation decreased $4.6 million during the nine months ended September 30, 1999 primarily due to lower gas purchases due to lower generation. Purchased power increased $14.9 million during the nine months ended September 30, 1999, when compared to the same period in 1998, due to an increase in capacity costs of $9.9 million related to new purchase power contracts and an increase in wholesale purchases. SPS generates substantially all of its power for sale to its 60 firm retail and wholesale customers and sells non-firm energy as the market demands. Similarly, SPS will purchase low-cost non-firm energy when available and as needed to meet customer requirements. SPS has fuel cost adjustment mechanisms which recognize the majority of the effects of changes in fuel used in generation and purchased power costs and allow recovery of such costs on a timely basis. As a result, the changes in revenues associated with these mechanisms during the nine months ended September 30, 1999, when compared to the nine months ended September 30, 1998, had little impact on net income. (See discussion on "SPS Electric Cost Adjustment Mechanisms" Note 4. Regulatory Matters - in Item 1. FINANCIAL STATEMENTS). Non-Fuel Operating Expenses Other operating and maintenance expenses decreased $6.1 million during the nine months ended September 30, 1999, when compared to the same period in 1998, primarily due to lower general and administrative expenses, and the continued deployment of cost saving programs instituted as part of the PSCo/SPS Merger. These decreases were offset, in part, by higher maintenance costs. Taxes other than income taxes increased $3.2 million during the nine months ended September 30, 1999, as compared to the same period in 1998, primarily due to higher property and franchise taxes. Income taxes decreased $1.8 million during the nine months ended September 30, 1999, as compared to the same period in 1998, primarily due to the effect of lower pre-tax income. The effective income tax rate for both the nine months ending September 30, 1999 and 1998 was 37.3%. Other Income and Deductions - Net Other income and deductions-net increased $1.2 million during the nine months ended September 30, 1999, as compared to the same period in 1998, primarily due to the absence of PSCo/SPS Merger and business integration expenses in 1999 ($1.2 million expensed in 1998). Interest Charges Interest charges increased $2.1 million during the nine months ended September 30, 1999, as compared to the same period in 1998, primarily due to higher long-term debt costs, resulting from the issuance of $100 million in new debt in March of 1999 and a decrease in the allowance for funds used during construction of approximately $2.2 million resulting from lower construction activities. The new debt issuance was used in part to pay down short-term borrowings, thus lowering other interest expense ($3.3 million). Commitments and Contingencies See Note 5. Commitments and Contingencies in Item 1. FINANCIAL STATEMENTS. Financing Activities Discussion relating to SPS's financing activities is covered under "Financing Activities" in NCE's Management's Discussion and Analysis of Financial Condition and Results of Operations. 61 PART II - OTHER INFORMATION Item 1. Legal Proceedings Part 1. See Note 5. Commitments and Contingencies in Item 1, Part 1. Item 6. Exhibits and Reports on Form 8-K (a) Exhibits 12(a) Computation of Ratio of Consolidated Earnings to Consolidated Fixed Charges for PSCo is set forth at page 65 herein. 12(b) Computation of Ratio of Consolidated Earnings to Consolidated Fixed Charges for SPS is set forth at page 66 herein. 15(a) Letter from Arthur Andersen LLP regarding unaudited interim information is set forth at page 67 herein for NCE. 15(b) Letter from Arthur Andersen LLP regarding unaudited interim information is set forth at page 68 herein for PSCo. 15(c) Letter from Arthur Andersen LLP regarding unaudited interim information is set forth at page 69 herein for SPS. 27(a) Financial Data Schedule for NCE as of September 30, 1999. 27(b) Financial Data Schedule for PSCo as of September 30, 1999. 27(c) Financial Data Schedule for SPS as of September 30, 1999. (b) Reports on Form 8-K The following report on Form 8-K was filed since the beginning of the third quarter of 1999. - - A report on Form 8-K dated July 13, 1999, was filed by PSCo on July 22, 1999. The items reported were Item 5. Other Events: Documents related to the issuance of $200,000,000 aggregate principal amount on July 16, 1999 of Series A Senior Notes and Item 7. Financial Statements and Exhibits. 62 NEW CENTURY ENERGIES, INC. SIGNATURE Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, New Century Energies, Inc. has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized on the 15th day of November, 1999. NEW CENTURY ENERGIES, INC. By /s/ R. C. Kelly --------------------------------- R. C. Kelly Executive Vice President and Chief Financial Officer PUBLIC SERVICE COMPANY OF COLORADO SIGNATURE Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, Public Service Company of Colorado has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized on the 15th day of November, 1999. PUBLIC SERVICE COMPANY OF COLORADO By /s/Brian P. Jackson --------------------------------- Brian P. Jackson Senior Vice President, Finance and Administrative Services, Chief Financial Officer and Treasurer SOUTHWESTERN PUBLIC SERVICE COMPANY SIGNATURE Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, Southwestern Public Service Company has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized on the 15th day of November, 1999. SOUTHWESTERN PUBLIC SERVICE COMPANY By /s/Brian P. Jackson --------------------------------- Brian P. Jackson Senior Vice President, Finance and Administrative Services, Chief Financial Officer and Treasurer 63 EXHIBIT INDEX 2(a)1* NCE/NSP Agreement and Plan of Merger dated March 24, 1999 (Form 8-K, March 24, 1999, Exhibit 2.1). 3(a)1* NCE Restated Articles of Incorporation dated December 8, 1995 (Form S-4, Exhibit 3(a)). 3(a)2* PSCo Amended and Restated Articles of Incorporation dated July 10, 1998 (Form 10-K, December 31, 1998, Exhibit 3(a)1). 3(a)3* SPS Amended and Restated Articles of Incorporation dated September 30, 1997 (Form 10-K, December 31, 1997, Exhibit 3(a)2). 3(b)1* NCE Restated By-laws dated December 15, 1998 (Form 10-K, December 31, 1998, Exhibit 3(b)1). 3(b)2* PSCo By-laws dated November 20, 1997 (Form 10-K, December 31, 1997, Exhibit 3(b)1). 3(b)3* SPS By-laws dated September 29, 1997 (Form 10-K, December 31, 1997, Exhibit 3(b)2). 12(a) Computation of Ratio of Consolidated Earnings to Consolidated Fixed Charges for PSCo is set forth at page 65 herein. 12(b) Computation of Ratio of Consolidated Earnings to Consolidated Fixed Charges for SPS is set forth at page 66 herein. 15(a) Letter from Arthur Andersen LLP regarding unaudited interim information is set forth at page 67 herein for NCE. 15(b) Letter from Arthur Andersen LLP regarding unaudited interim information is set forth at page 68 herein for PSCo. 15(c) Letter from Arthur Andersen LLP regarding unaudited interim information is set forth at page 69 herein for SPS. 27(a) Financial Data Schedule for NCE as of September 30, 1999. 27(b) Financial Data Schedule for PSCo as of September 30, 1999. 27(c) Financial Data Schedule for SPS as of September 30, 1999. * Previously filed as indicated and incorporated herein by reference. 64 EXHIBIT 12(a) PUBLIC SERVICE COMPANY OF COLORADO AND SUBSIDIARIES COMPUTATION OF RATIO OF CONSOLIDATED EARNINGS TO CONSOLIDATED FIXED CHARGES (not covered by Report of Independent Public Accountants) Nine Months Ended September 30, 1999 1998 ---- ---- (Thousands of Dollars, except ratios) Fixed charges: Interest on long-term debt................... $ 88,890 $ 86,899 Interest on borrowings against corporate-owned life insurance contracts................... 43,342 38,004 Other interest............................... 19,671 14,967 Amortization of debt discount and expense less premium .............................. 3,331 3,148 Interest component of rental expense......... 6,720 6,166 Dividends on PSCo obligated mandatorily redeemable preferred securities............ 11,400 5,911 ------ ------ Total...................................... $173,354 $155,095 ======== ======== Earnings (before fixed charges and taxes on income): Net income................................... $150,508 $143,820 Fixed charges as above....................... 173,354 155,095 Provisions for Federal and state taxes on income, net of investment tax credit amortization.... ........................... 67,154 72,184 ------ ------ Total...................................... $391,016 $371,099 ======== ======== Ratio of earnings to fixed charges.............. 2.26 2.39 ====== ====== 65 EXHIBIT 12(b) SOUTHWESTERN PUBLIC SERVICE COMPANY AND SUBSIDIARIES COMPUTATION OF RATIO OF CONSOLIDATED EARNINGS TO CONSOLIDATED FIXED CHARGES (not covered by Report of Independent Public Accountants) Nine Months Ended September 30, 1999 1998 ---- ---- (Thousands of Dollars, except ratios) Fixed charges: Interest on long-term debt................... $ 36,112 $ 32,972 Other interest............................... 3,989 7,275 Amortization of debt discount and expense less premium ................................... 1,777 1,682 Interest component of rental expense......... 573 606 Dividends on SPS obligated mandatorily redeemable preferred securities............ 5,888 5,888 ------ ------ Total...................................... $ 48,339 $ 48,423 ======== ======== Earnings (before fixed charges and taxes on income): Net income................................... $ 88,760 $ 91,985 Fixed charges as above....................... 48,339 48,423 Provisions for Federal and state taxes on income, net of investment tax credit amortization.... .......................... 52,868 54,709 ------ ------ Total...................................... $189,967 $195,117 ======== ======== Ratio of earnings to fixed charges.............. 3.93 4.03 ==== ==== 66 EXHIBIT 15(a) November 9, 1999 New Century Energies, Inc.: We are aware that New Century Energies, Inc. has incorporated by reference in its Registration Statement (Form S-8, File No. 333-28639) pertaining to the Omnibus Incentive Plan; its Registration Statement (Form S-3, File No. 333-28637) pertaining to the Dividend Reinvestment and Cash Payment Plan; its Registration Statements (Form S-3, File Nos. 333-40361 and 333-64067) pertaining to the registration of NCE Common Stock and its Registration Statement (Form S-8, File No. 333-58117) pertaining to the NCE Employee Investment Plan and NCE Employees' Savings and Stock Ownership Plan its Form 10-Q for the quarter ended September 30, 1999, which includes our report dated November 9, 1999, covering the unaudited consolidated condensed financial statements contained therein. Pursuant to Regulation C of the Securities Act of 1933, that report is not considered a part of the registration statement prepared or certified by our Firm or a report prepared or certified by our Firm within the meaning of Sections 7 and 11 of the Act. Very truly yours, ARTHUR ANDERSEN 67 EXHIBIT 15(b) November 9, 1999 Public Service Company of Colorado: We are aware that Public Service Company of Colorado has incorporated by reference in its Registration Statement (Form S-3, File No. 33-62233) pertaining to the Automatic Dividend Reinvestment and Common Stock Purchase Plan; its Registration Statement (Form S-3, File No. 33-37431) as amended on December 4, 1990, pertaining to the shelf registration of Public Service Company of Colorado's First Mortgage Bonds; its Registration Statement (Form S-8, File No. 33-55432) pertaining to the Omnibus Incentive Plan; its Registration Statement (Form S-3, File No. 33-51167) pertaining to the shelf registration of Public Service Company of Colorado's First Collateral Trust Bonds; its Registration Statement (Form S-3, File No. 33-54877) pertaining to the shelf registration of Public Service Company of Colorado's First Collateral Trust Bonds and Cumulative Preferred Stock and its Registration Statement (Form S-3, File No. 333-81791) pertaining to the shelf registration of Public Service Company of Colorado's Senior Debt Securities its Form 10-Q for the quarter ended September 30, 1999, which includes our report dated November 9, 1999, covering the unaudited consolidated condensed financial statements contained therein. Pursuant to Regulation C of the Securities Act of 1933, that report is not considered a part of the registration statement prepared or certified by our Firm or a report prepared or certified by our Firm within the meaning of Sections 7 and 11 of the Act. Very truly yours, ARTHUR ANDERSEN 68 EXHIBIT 15(c) November 9, 1999 Southwestern Public Service Company: We are aware that Southwestern Public Service Company has incorporated by reference in its Registration Statement (Form S-3, File No. 333-05199) pertaining to Southwestern Public Service Company's Preferred Stock and Debt Securities; its Registration Statement (Form S-8, File No. 33-27452) pertaining to Southwestern Public Service Company's 1989 Stock Incentive Plan and its Registration Statement (Form S-8, File No. 33-57869) pertaining to Southwestern Public Service Company's Employee Investment Plan and Non-Qualified Salary Deferral Plan its Form 10-Q for the quarter ended September 30, 1999, which includes our report dated November 9, 1999, covering the unaudited condensed financial statements contained therein. Pursuant to Regulation C of the Securities Act of 1933, that report is not considered a part of the registration statement prepared or certified by our Firm or a report prepared or certified by our Firm within the meaning of Sections 7 and 11 of the Act. Very truly yours, ARTHUR ANDERSEN 69 EX-27.1 2 NCE FDS 3RD QTR 99
UT THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM NEW CENTURY ENERGIES, INC. CONSOLIDATED CONDENSED BALANCE SHEET AS OF SEPTEMBER 30, 1999 AND CONSOLIDATED CONDENSED STATEMENTS OF INCOME AND CASH FLOWS FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1999 AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS. 0001004858 New Century Energies, Inc. 1,000 9-MOS DEC-31-1998 SEP-30-1999 PER-BOOK 6,149,213 443,475 887,391 620,152 0 8,100,231 115,534 1,790,328 788,613 2,699,232 294,000 0 2,237,388 19,400 0 501,691 332,145 0 34,681 1,495 1,980,199 8,100,231 2,528,416 98,339 2,029,625 2,029,625 498,791 9,900 508,691 161,890 248,462 0 0 200,526 131,284 374,944 2.16 2.16
EX-27.2 3 PSCO FDS 3RD QTR 99
UT THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM PUBLIC SERVICE COMPANY OF COLORADO AND SUBSIDIARIES CONSOLIDATED CONDENSED BALANCE SHEET AS OF SEPTEMBER 30, 1999 AND CONSOLIDATED CONDENSED STATEMENTS OF INCOME AND CASH FLOWS FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1999 AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS. 0000081018 Public Service Company of Colorado 1,000 9-MOS DEC-31-1998 SEP-30-1999 PER-BOOK 4,275,040 204,095 503,860 346,251 0 5,329,246 0 1,302,119 338,519 1,640,638 194,000 0 1,584,327 0 0 396,300 240,451 0 34,681 1,405 1,237,444 5,329,246 1,639,235 67,154 1,304,935 1,372,089 267,146 (621) 266,525 116,017 150,508 0 150,508 137,202 92,221 315,654 0.00 0.00
EX-27.3 4 SPS FDS 3RD QTR 99
UT THIS SCHEDULE CONTAINS SUMMARY FINANCIAL INFORMATION EXTRACTED FROM SOUTHWESTERN PUBLIC SERVICE COMPANY CONDENSED BALANCE SHEET AS OF SEPTEMBER 30, 1999 AND CONDENSED STATEMENTS OF INCOME AND CASH FLOWS FOR THE NINE MONTHS ENDED SEPTEMBER 30, 1999 AND IS QUALIFIED IN ITS ENTIRETY BY REFERENCE TO SUCH FINANCIAL STATEMENTS. 0000092521 Southwestern Public Service Company 1,000 9-MOS DEC-31-1998 SEP-30-1999 PER-BOOK 1,762,548 124,753 188,972 174,705 0 2,250,978 0 348,402 415,299 763,701 100,000 0 605,840 0 0 103,391 90,113 0 0 0 587,933 2,250,978 717,253 52,868 536,631 589,499 127,754 6,809 134,563 45,803 88,760 0 88,760 63,280 37,889 78,084 0.00 0.00
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