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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For The Quarterly Period Ended March 31, 2005
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from __________ to __________.
Commission Registrant; State of Incorporation; IRS Employer
File Number Address; and Telephone Number Identification Number
- ----------- ----------------------------- ---------------------
1-13739 UNISOURCE ENERGY CORPORATION 86-0786732
(An Arizona Corporation)
One South Church Avenue, Suite 100
Tucson, AZ 85701
(520) 571-4000
1-5924 TUCSON ELECTRIC POWER COMPANY 86-0062700
(An Arizona Corporation)
One South Church Avenue, Suite 100
Tucson, AZ 85701
(520) 571-4000
Indicate by check mark whether each registrant (1) has filed all reports
required to be filed by Section 13 or 15(d) of the Securities Exchange Act of
1934 during the preceding 12 months (or for such shorter period that the
registrant was required to file such reports), and (2) has been subject to such
filing requirements for the past 90 days. Yes X No
----- -----
Indicate by check mark whether the registrant is an accelerated filer (as
defined in Rule 12b-2 of the Exchange Act).
UniSource Energy Corporation Yes X No
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Tucson Electric Power Company Yes No X
----- -----
At May 4, 2005, 34,556,088 shares of UniSource Energy Corporation Common
Stock, no par value (the only class of Common Stock), were outstanding.
At May 4, 2005, 32,139,555 shares of Tucson Electric Power Company's common
stock, no par value, were outstanding, of which 32,139,434 shares were held by
UniSource Energy Corporation.
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This combined Form 10-Q is separately filed by UniSource Energy Corporation and
Tucson Electric Power Company. Information contained in this document relating
to Tucson Electric Power Company is filed by UniSource Energy Corporation and
separately by Tucson Electric Power Company on its own behalf. Tucson Electric
Power Company makes no representation as to information relating to UniSource
Energy Corporation or its subsidiaries, except as it may relate to Tucson
Electric Power Company.
TABLE OF CONTENTS
Definitions v
-- PART I --
Reports of Independent Registered Public Accounting Firm 1
Item 1. - Financial Statements 3
UniSource Energy Corporation
Comparative Condensed Consolidated Statements of Income (Loss) 3
Comparative Condensed Consolidated Statements of Cash Flows 4
Comparative Condensed Consolidated Balance Sheets 5
Condensed Consolidated Statement of Changes in Stockholders' Equity 6
Tucson Electric Power Company
Comparative Condensed Consolidated Statements of Income (Loss) 7
Comparative Condensed Consolidated Statements of Cash Flows 8
Comparative Condensed Consolidated Balance Sheets 9
Condensed Consolidated Statement of Changes in Stockholders' Equity 10
Notes to Condensed Consolidated Financial Statements 11
Note 1. Nature of Operations, Basis of Accounting Presentation and
Equity-Based Compensation 11
Note 2. Regulatory Matters 13
Note 3. Debt and Credit Facilities 14
Note 4. Business Segments 17
Note 5. Accounting for Derivative Instruments and Trading Activities 18
Note 6. Commitments and Contingencies 20
Note 7. TEP Wholesale Accounts Receivable and Allowances 22
Note 8. UniSource Energy Earnings Per Share (EPS) 22
Note 9. Employee Benefit Plans 23
Note 10. Share-Based Compensation Plans 24
Note 11. Income and Other Taxes 25
Note 12. New Accounting Pronouncements 26
Note 13. Supplemental Cash Flow Information 27
Note 14. Review by Independent Accountants 28
Item 2. - Management's Discussion and Analysis of Financial Condition
and Results of Operations 29
UniSource Energy Consolidated 29
Results of Operations 30
Contribution by Business Segment 30
Liquidity and Capital Resources 31
Tucson Electric Power Company 35
Results of Operations 35
Factors Affecting Results of Operations 37
Liquidity and Capital Resources 40
UNS Gas 44
Results of Operations 44
Factors Affecting Results of Operations 45
Liquidity and Capital Resources 45
UNS Electric 47
Results of Operations 47
Factors Affecting Results of Operations 48
Liquidity and Capital Resources 48
Global Solar Energy, Inc. 50
Results of Operations 50
Other 50
Results of Operations 50
Critical Accounting Estimates 51
New Accounting Pronouncements 57
Safe Harbor for Forward-Looking Statements 58
ii
Item 3. - Quantitative and Qualitative Disclosures about Market Risk 59
Item 4. - Controls and Procedures 62
PART II - OTHER INFORMATION
Item 1. - Legal Proceedings 62
Item 5. - Other Information 63
TEP Credit Agreement 63
Non-GAAP Measures 63
SEC Reports Available on UniSource Energy's Website 66
Item 6. Exhibits 67
Signatures 68
Exhibit Index 69
iii
DEFINITIONS
The abbreviations and acronyms used in the 2005 First Quarter 10-Q are defined
below:
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ACC........................... Arizona Corporation Commission.
ACC Holding Company Order..... The order approved by the ACC in November
1997 allowing TEP to form a holding company.
AHMSA......................... Altos Hornos de Mexico, S.A. de C.V. AHMSA
owns 50% of Sabinas.
AMT........................... Alternative Minimum Tax.
APS........................... Arizona Public Service Company.
Btu........................... British thermal unit(s).
Capacity...................... The ability to produce power; the most power
a unit can produce or the maximum that can
be taken under a contract; measured in MWs.
CISO.......................... California Independent System Operator.
Citizens...................... Citizens Communications Company.
Citizens Settlement Agreement. An agreement with the ACC Staff dated
April 1, 2003, addressing rate case and
financing issues in the acquisition by
UniSource Energy of Citizens' Arizona gas and
electric assets.
Common Stock.................. UniSource Energy's common stock, without
par value.
Company or UniSource Energy... UniSource Energy Corporation.
Convertible Senior Notes...... UniSource Energy's 4.50% Convertible Senior
Notes due March 1, 2035.
Emissions Allowance(s)........ An allowance issued by the EPA which permits
emission of one ton of sulfur dioxide or one
ton of nitrogen oxide. These allowances
can be bought and sold.
Energy........................ The amount of power produced over a
given period of time; measured in MWh.
EPA........................... The Environmental Protection Agency.
ESP........................... Energy Service Provider.
Express Line.................. 345-kV circuit connecting Springerville
Unit 2 to the Tucson 138-kV system.
FAS 71........................ Statement of Financial Accounting Standards
No. 71: Accounting for the Effects of
Certain Types of Regulation.
FAS 133....................... Statement of Financial Accounting
Standards No 133: Accounting for Derivative
Instruments and Hedging Activities,
as amended.
FAS 143....................... Statement of Financial Accounting
Standards No. 143: Accounting for Asset
Retirement Obligations.
FERC.......................... Federal Energy Regulatory Commission.
First Collateral Trust Bonds.. Bonds issued under the Indenture of Trust,
dated as of August 1, 1998, of TEP to the
Bank of New York, successor trustee.
First Mortgage Bonds.......... First mortgage bonds issued under the
Indenture, dated as of April 1, 1941, of TEP
to J.P. Morgan Chase Bank, successor trustee,
as supplemented and amended.
Four Corners.................. Four Corners Generating Station.
Global Solar.................. Global Solar Energy, Inc., a company that
develops and manufactures thin-film
photovoltaic cells. Millennium owns 99% of
Global Solar.
Haddington.................... Haddington Energy Partners II, LP, a limited
partnership that funds energy-related
investments.
Heating Degree Days........... An index used to measure the impact of
weather on energy usage calculated by
subtracting the average of the high and low
daily temperatures from 65.
IDBs.......................... Industrial development revenue or pollution
control revenue bonds.
IPS........................... Infinite Power Solutions, Inc., a company
that develops thin-film batteries.
Millennium owns 72% of IPS.
IRS........................... Internal Revenue Service.
ISO........................... Independent System Operator.
ITC........................... Investment Tax Credit.
kWh........................... Kilowatt-hour(s).
kV............................ Kilovolt(s).
iv
LIBOR......................... London Interbank Offered Rate.
LOC........................... Letter of Credit.
Luna.......................... Luna Energy Facility.
MEG........................... Millennium Environment Group, Inc., a
wholly-owned subsidiary of Millennium,
which manages and trades emission
allowances, coal, and related
financial instruments.
MicroSat...................... MicroSat Systems, Inc. is a company
formed to develop and commercialize
small-scale satellites. Millennium
currently owns 35%.
Millennium.................... Millennium Energy Holdings, Inc.,
a wholly-owned subsidiary of
UniSource Energy.
Mimosa........................ Minerales de Monclova, S.A. de C.V.,
an owner of coal and associated gas
reserves and a supplier of
metallurgical coal to the steel
industry and thermal coal to the
Mexican electricity commission.
Sabinas owns 19.5% of Mimosa.
MMBtus........................ Million British Thermal Units.
MW............................ Megawatt(s).
MWh........................... Megawatt-hour(s).
Navajo........................ Navajo Generating Station.
NOL........................... Net Operating Loss carryback or
carryforward for income tax purposes.
PGA........................... Purchased Gas Adjustor, a retail rate
mechanism designed to recover the cost
of gas purchased for retail gas customers.
PNM........................... Public Service Company of New Mexico.
PNMR.......................... PNM Resources, Inc.
Powertrusion.................. POWERTRUSION International, Inc., a
company owned 77% by Millennium,
which manufactures lightweight utility poles.
PPFAC......................... Purchased Power and Fuel Adjustment Clause.
PWCC.......................... Pinnacle West Capital Corporation.
Repurchased Bonds............. $221 million of fixed-rate tax-exempt bonds
that TEP will purchase from bondholders on
May 11, 2005, pursuant to a tender offer
that expired on May 5, 2005.
RTO........................... Regional Transmission Organization.
Rules......................... Retail Electric Competition Rules.
Sabinas....................... Carboelectrica Sabinas, S. de R.L. de C.V.,
a Mexican limited liability company.
Millennium owns 50% of Sabinas.
Saguaro Utility............... An Arizona limited partnership, whose
general partner was Sage Mountain, L.L.C.
and whose limited partners included
investment funds affiliated with Kohlberg
Kravis Roberts & Co., L.P., J.P. Morgan
Partners, L.L.C. and Wachovia Capital
Partners.
San Carlos.................... San Carlos Resources Inc., a wholly-owned
subsidiary of TEP.
San Juan...................... San Juan Generating Station.
Second Mortgage Bonds......... TEP's second mortgage bonds issued under
the Indenture of Mortgage and Deed of Trust,
dated as of December 1, 1992, of TEP to The
Bank of New York, successor trustee, as
supplemented.
Sempra........................ Sempra Energy Trading Company.
SCE........................... Southern California Edison Company.
SES........................... Southwest Energy Solutions, Inc., a
wholly-owned subsidiary of Millennium.
Settlement Agreement.......... TEP's Settlement Agreement approved by the
ACC in November 1999 that provided for
electric retail competition and
transition asset recovery.
Springerville................. Springerville Generating Station.
Springerville Coal Handling
Facilities Leases........ Leveraged lease arrangements relating to the
coal handling facilities serving
Springerville.
Springerville Common
Facilities............... Facilities at Springerville used in common
with Springerville Unit 1 and Springerville
Unit 2.
Springerville Common
Facilities Leases........ Leveraged lease arrangements relating to an
undivided one-half interest in certain
Springerville Common Facilities.
Springerville Unit 1.......... Unit 1 of the Springerville Generating
Station.
v
Springerville Unit 1 Lease.... Leveraged lease arrangement relating to
Springerville Unit 1 and an undivided
one-half interest in certain Springerville
Common Facilities.
Springerville Unit 2.......... Unit 2 of the Springerville Generating
Station.
SRP........................... Salt River Project Agricultural Improvement
and Power District.
Sundt......................... H. Wilson Sundt Generating Station
(formerly known as the Irvington Generating
Station).
Sundt Lease................... The leveraged lease arrangement relating to
Sundt Unit 4.
SWG........................... Southwest Gas Corporation.
TEP........................... Tucson Electric Power Company, the principal
subsidiary of UniSource Energy.
TEP Credit Agreement.......... Credit Agreement between TEP and a syndicate
of banks, dated as of May 4, 2005.
TEP Revolving Credit Facility. $60 million revolving credit facility
entered into under the TEP Credit Agreement,
dated as of May 4, 2005, between a
syndicate of banks and TEP.
Therm......................... A unit of heating value equivalent to
100,000 British thermal units (Btu).
Tri-State..................... Tri-State Generation and Transmission
Association.
TruePricing................... TruePricing, Inc., a start-up company
established to market energy related
products.
UED........................... UniSource Energy Development Company,
a wholly-owned subsidiary of UniSource
Energy, which engages in developing
generation resources and other project
development services and related
activities.
UES........................... UniSource Energy Services, Inc., an
intermediate holding company
established to own the operating
companies (UNS Gas and UNS Electric)
which acquired the Citizens Arizona
gas and electric utility assets.
UniSource Credit Agreement.... Credit Agreement between UniSource Energy
and a syndicate of banks, dated
as of April 15, 2005.
UniSource Energy.............. UniSource Energy Corporation.
UNS Electric.................. UNS Electric, Inc., a wholly-owned
subsidiary of UES, which acquired
the Citizens Arizona electric utility assets.
UNS Gas....................... UNS Gas, Inc., a wholly-owned subsidiary of
UES, which acquired the Citizens Arizona gas
utility assets.
UNS Gas/UNS Electric Revolver. A $40 million revolving credit facility
entered into by UNS Gas and UNS Electric
on April 15, 2005.
Valencia...................... Valencia power plant owned by UNS Electric.
WestConnect................... The proposed for-profit RTO in which TEP is
a participant.
vi
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders of
UniSource Energy Corporation:
We have reviewed the accompanying condensed consolidated balance sheet of
UniSource Energy Corporation and its subsidiaries (the Company) as of March 31,
2005, and the related condensed consolidated statements of income (loss) and of
cash flows for each of the three-month periods ended March 31, 2005 and 2004 and
the condensed consolidated statement of changes in stockholders' equity for the
three-month period ended March 31, 2005. These interim financial statements are
the responsibility of the Company's management.
We conducted our review in accordance with the standards of the Public Company
Accounting Oversight Board (United States). A review of interim financial
information consists principally of applying analytical procedures and making
inquiries of persons responsible for financial and accounting matters. It is
substantially less in scope than an audit conducted in accordance with the
standards of the Public Company Accounting Oversight Board, 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 accompanying condensed consolidated interim financial statements
for them to be in conformity with accounting principles generally accepted in
the United States of America.
We have previously audited, in accordance with the standards of the Public
Company Accounting Oversight Board (United States), the consolidated balance
sheet as of December 31, 2004, and the related consolidated statements of
income, of cash flows and of changes in stockholders' equity for the year then
ended, management's assessment of the effectiveness of the Company's internal
control over financial reporting as of December 31, 2004 and the effectiveness
of the Company's internal control over financial reporting as of December 31,
2004; and in our report dated March 16, 2005, we expressed unqualified opinions
thereon. The consolidated financial statements and management's assessment of
the effectiveness of internal control over financial reporting referred to above
are not presented herein. In our opinion, the information set forth in the
accompanying consolidated balance sheet information as of March 31, 2005, is
fairly stated in all material respects in relation to the consolidated balance
sheet from which it has been derived.
PRICEWATERHOUSECOOPERS LLP
Los Angeles, California
May 6, 2005
1
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders of
Tucson Electric Power Company:
We have reviewed the accompanying condensed consolidated balance sheet of Tucson
Electric Power Company (the Company) as of March 31, 2005, and the related
condensed consolidated statements of income (loss) and of cash flows for each of
the three-month periods ended March 31, 2005 and 2004 and the condensed
consolidated statement of changes in stockholders' equity for the three-month
period ended March 31, 2005. These interim financial statements are the
responsibility of the Company's management.
We conducted our review in accordance with the standards of the Public Company
Accounting Oversight Board (United States). A review of interim financial
information consists principally of applying analytical procedures and making
inquiries of persons responsible for financial and accounting matters. It is
substantially less in scope than an audit conducted in accordance with the
standards of the Public Company Accounting Oversight Board, 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 accompanying condensed consolidated interim financial statements
for them to be in conformity with accounting principles generally accepted in
the United States of America.
We previously audited in accordance with the standards of the Public Company
Accounting Oversight Board (United States), the consolidated balance sheet as of
December 31, 2004, and the related consolidated statements of income, of cash
flows, and of changes in stockholders' equity for the year then ended (not
presented herein), and in our report dated March 16, 2005 we expressed an
unqualified opinion on those consolidated financial statements. In our opinion,
the information set forth in the accompanying consolidated balance sheet
information as of March 31, 2005, is fairly stated in all material respects in
relation to the consolidated balance sheet from which it has been derived.
PRICEWATERHOUSECOOPERS LLP
Los Angeles, California
May 6, 2005
2
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
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UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME (LOSS)
Three Months Ended
March 31,
2005 2004
(UNAUDITED)
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-Thousands of Dollars-
OPERATING REVENUES
Electric Retail Sales $ 171,590 $ 174,363
Electric Wholesale Sales 39,180 41,700
Gas Revenue 46,549 48,801
Other Revenues 3,610 5,220
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TOTAL OPERATING REVENUES 260,929 270,084
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OPERATING EXPENSES
Fuel 47,291 47,449
Purchased Energy 64,407 59,502
Other Operations and Maintenance 61,492 63,579
Depreciation and Amortization 34,824 35,136
Amortization of Transition Recovery Asset 9,487 8,597
Taxes Other Than Income Taxes 13,499 13,111
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TOTAL OPERATING EXPENSES 231,000 227,374
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OPERATING INCOME 29,929 42,710
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OTHER INCOME (DEDUCTIONS)
Interest Income 4,961 4,869
Other Income 2,261 8,715
Other Expense (2,351) (1,016)
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TOTAL OTHER INCOME (DEDUCTIONS) 4,871 12,568
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INTEREST EXPENSE
Long-Term Debt 20,352 23,118
Interest on Capital Leases 19,746 20,044
Other Interest Expense, Net of Amounts Capitalized 11 (214)
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TOTAL INTEREST EXPENSE 40,109 42,948
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INCOME (LOSS) BEFORE INCOME TAXES (5,309) 12,330
Income Tax Expense (Benefit) (1,526) 5,909
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NET INCOME (LOSS) $ (3,783) $ 6,421
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WEIGHTED-AVERAGE SHARES OF COMMON STOCK OUTSTANDING (000) 34,635 34,185
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BASIC EARNINGS (LOSS) PER SHARE $ (0.11) $ 0.19
=================================================================================================
DILUTED EARNINGS (LOSS) PER SHARE $ (0.11) $ 0.18
=================================================================================================
DIVIDENDS PAID PER SHARE $ 0.19 $ 0.16
=================================================================================================
See Notes to Condensed Consolidated Financial Statements.
3
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Three Months Ended
March 31,
2005 2004
(UNAUDITED)
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-Thousands of Dollars-
CASH FLOWS FROM OPERATING ACTIVITIES
Cash Receipts from Electric Retail Sales $ 206,194 $ 200,489
Cash Receipts from Electric Wholesale Sales 52,111 56,327
Cash Receipts from Gas Sales 55,568 56,981
MEG Cash Receipts from Trading Activity 38,566 34,357
Interest Received 10,488 10,504
Income Tax Refunds Received 928 286
Performance Deposits 6,349 (7,052)
Other Cash Receipts 2,666 4,121
Fuel Costs Paid (48,503) (46,073)
Purchased Energy Costs Paid (82,143) (76,681)
Wages Paid, Net of Amounts Capitalized (29,336) (25,051)
Payment of Other Operations and Maintenance Costs (39,059) (35,905)
MEG Cash Payments for Trading Activity (39,044) (28,278)
Capital Lease Interest Paid (38,387) (40,308)
Taxes Paid, Net of Amounts Capitalized (22,774) (22,336)
Interest Paid, Net of Amounts Capitalized (29,142) (30,135)
Income Taxes Paid (3,500) (7,000)
Other Cash Payments (930) (207)
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NET CASH FLOWS - OPERATING ACTIVITIES 40,052 44,039
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CASH FLOWS FROM INVESTING ACTIVITIES
Capital Expenditures (44,872) (31,370)
Proceeds from Investment in Springerville Lease Debt and Equity 8,251 8,054
Other Cash Receipts 5,616 -
Investment in and Loans to Equity Investees (216) (628)
Return of Investment from Millennium Energy Business - 267
Payments for Investment in Springerville Lease Debt and Equity - (4,499)
Other Cash Payments - (4)
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NET CASH FLOWS - INVESTING ACTIVITIES (31,221) (28,180)
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CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Issuance of Long-Term Debt 150,000 -
Repayments of Long-Term Debt (53,150) (1,232)
Payments on Capital Lease Obligations (48,377) (43,632)
Proceeds from Borrowings under Revolving Credit Facility - 20,000
Payments on Borrowings under Revolving Credit Facility - (20,000)
Other Cash Receipts 5,960 4,615
Payment of Debt Issue/Retirement Costs (5,126) (8,959)
Common Stock Dividends Paid (6,537) (5,439)
Other Cash Payments (1,375) (1,253)
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NET CASH FLOWS - FINANCING ACTIVITIES 41,395 (55,900)
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Net Increase (Decrease) in Cash and Cash Equivalents 50,226 (40,041)
Cash and Cash Equivalents, Beginning of Year 154,028 101,266
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CASH AND CASH EQUIVALENTS, END OF PERIOD $ 204,254 $ 61,225
=================================================================================================
See Note 13 for supplemental cash flow information.
See Notes to Condensed Consolidated Financial Statements.
4
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED BALANCE SHEETS
March 31, December 31,
2005 2004
(UNAUDITED)
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ASSETS - Thousands of Dollars -
UTILITY PLANT
Plant in Service $ 3,064,432 $ 3,033,405
Utility Plant under Capital Leases 723,901 723,901
Construction Work in Progress 126,633 116,161
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TOTAL UTILITY PLANT 3,914,966 3,873,467
Less Accumulated Depreciation and Amortization (1,377,294) (1,348,017)
Less Accumulated Amortization of Capital Lease Assets (451,323) (444,313)
- -------------------------------------------------------------------------------------------------
TOTAL UTILITY PLANT - NET 2,086,349 2,081,137
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INVESTMENTS AND OTHER PROPERTY
Investments in Lease Debt and Equity 162,406 170,893
Other 82,642 85,035
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TOTAL INVESTMENTS AND OTHER PROPERTY 245,048 255,928
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CURRENT ASSETS
Cash and Cash Equivalents 204,254 154,028
Trade Accounts Receivable 87,652 107,694
Unbilled Accounts Receivable 39,861 55,350
Allowance for Doubtful Accounts (16,604) (16,492)
Materials and Fuel Inventory 67,593 62,225
Trading Assets 50,761 70,958
Current Regulatory Assets 9,922 9,653
Income Taxes Receivable 6,045 -
Deferred Income Taxes - Current 14,719 24,055
Interest Receivable - Current 5,409 10,475
Other 21,290 26,751
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TOTAL CURRENT ASSETS 490,902 504,697
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REGULATORY AND OTHER ASSETS
Transition Recovery Asset 214,541 224,029
Income Taxes Recoverable Through Future Revenues 43,498 44,624
Other Regulatory Assets 16,693 15,823
Other Assets 55,735 49,280
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TOTAL REGULATORY AND OTHER ASSETS 330,467 333,756
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TOTAL ASSETS $ 3,152,766 $ 3,175,518
=================================================================================================
CAPITALIZATION AND OTHER LIABILITIES
CAPITALIZATION
Common Stock Equity $ 578,524 $ 580,718
Capital Lease Obligations 655,957 701,931
Long-Term Debt 1,356,170 1,257,595
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TOTAL CAPITALIZATION 2,590,651 2,540,244
- -------------------------------------------------------------------------------------------------
CURRENT LIABILITIES
Current Obligations under Capital Leases 56,227 53,694
Current Maturities of Long-Term Debt - 1,725
Accounts Payable 62,159 95,276
Interest Accrued 26,414 60,679
Trading Liabilities 50,962 65,022
Taxes Accrued 45,528 53,192
Accrued Employee Expenses 14,479 19,216
Customer Deposits 15,183 14,794
Other 6,794 4,556
- -------------------------------------------------------------------------------------------------
TOTAL CURRENT LIABILITIES 277,746 368,154
- -------------------------------------------------------------------------------------------------
DEFERRED CREDITS AND OTHER LIABILITIES
Deferred Income Taxes - Noncurrent 113,212 101,753
Regulatory Liability - Net Cost of Removal for Interim Retirements 71,795 69,585
Other 99,362 95,782
- -------------------------------------------------------------------------------------------------
TOTAL DEFERRED CREDITS AND OTHER LIABILITIES 284,369 267,120
- -------------------------------------------------------------------------------------------------
COMMITMENTS AND CONTINGENCIES (NOTE 6)
- -------------------------------------------------------------------------------------------------
TOTAL CAPITALIZATION AND OTHER LIABILITIES $ 3,152,766 $ 3,175,518
=================================================================================================
See Notes to Condensed Consolidated Financial Statements.
5
UNISOURCE ENERGY CORPORATION
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY
Accumulated
Common Accumulated Other Total
Shares Common Earnings Comprehensive Stockholders'
Outstanding* Stock (Deficit) Income (Loss) Equity
- ------------------------------------------------------------------------------------------------------------------------------------
(UNAUDITED)
- Thousands of Dollars -
BALANCES AT DECEMBER 31, 2004 34,255 $ 677,119 $ (85,666) $ (10,735) $ 580,718
- ------------------------------------------------------------------------------------------------------------------------------------
Comprehensive Income (Loss):
2005 Year-to-Date Net Loss - - (3,783) - (3,783)
Unrealized Gain on Cash Flow Hedges
(net of $2,315 income tax expense) - - - 3,531 3,531
Reclassification of Realized Gain on
Cash Flow Hedges to Net Income
(net of $48 income tax expense) - - - (73) (73)
--------------
Total Comprehensive Loss (325)
--------------
Dividends Declared - - (6,537) - (6,537)
Shares Issued under Stock Compensation Plans 37 - - - -
Shares Issued for Stock Options 212 4,538 - - 4,538
Other - 130 - - 130
- ------------------------------------------------------------------------------------------------------------------------------------
BALANCES AT MARCH 31, 2005 34,504 $ 681,787 $ (95,986) $ (7,277) $ 578,524
====================================================================================================================================
* UniSource Energy has 75 million authorized shares of common stock.
See Notes to Condensed Consolidated Financial Statements.
6
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME (LOSS)
Three Months Ended
March 31,
2005 2004
(UNAUDITED)
- -------------------------------------------------------------------------------------------------
-Thousands of Dollars-
OPERATING REVENUES
Electric Retail Sales $ 140,206 $ 143,176
Electric Wholesale Sales 39,128 41,649
Other Revenues 2,572 2,149
- -------------------------------------------------------------------------------------------------
TOTAL OPERATING REVENUES 181,906 186,974
- -------------------------------------------------------------------------------------------------
OPERATING EXPENSES
Fuel 47,291 47,449
Purchased Power 12,861 6,252
Other Operations and Maintenance 47,977 47,829
Depreciation and Amortization 30,020 30,413
Amortization of Transition Recovery Asset 9,487 8,597
Taxes Other Than Income Taxes 11,149 10,746
- -------------------------------------------------------------------------------------------------
TOTAL OPERATING EXPENSES 158,785 151,286
- -------------------------------------------------------------------------------------------------
OPERATING INCOME 23,121 35,688
- -------------------------------------------------------------------------------------------------
OTHER INCOME (DEDUCTIONS)
Interest Income 4,816 4,861
Interest Income - Note Receivable from UniSource Energy 1,684 2,320
Other Income 1,765 1,164
Other Expense (1,432) (936)
- -------------------------------------------------------------------------------------------------
TOTAL OTHER INCOME (DEDUCTIONS) 6,833 7,409
- -------------------------------------------------------------------------------------------------
INTEREST EXPENSE
Long-Term Debt 16,979 20,381
Interest on Capital Leases 19,737 20,037
Other Interest Expense, Net of Amounts Capitalized 90 (189)
- -------------------------------------------------------------------------------------------------
TOTAL INTEREST EXPENSE 36,806 40,229
- -------------------------------------------------------------------------------------------------
INCOME (LOSS) BEFORE INCOME TAXES (6,852) 2,868
Income Tax Expense (Benefit) (2,162) 2,074
- -------------------------------------------------------------------------------------------------
NET INCOME (LOSS) $ (4,690) $ 794
=================================================================================================
See Notes to Condensed Consolidated Financial Statements.
7
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Three Months Ended
March 31,
2005 2004
(UNAUDITED)
- -------------------------------------------------------------------------------------------------
-Thousands of Dollars-
Cash Flows from Operating Activities
Cash Receipts from Electric Retail Sales $ 168,807 $ 165,683
Cash Receipts from Electric Wholesale Sales 52,047 56,258
Interest Received 10,327 10,452
Interest Received -- UniSource 11,013 -
Other Cash Receipts 1,090 1,257
Income Taxes Refunds Received 713 286
Fuel Costs Paid (48,503) (46,073)
Purchased Power Costs Paid (24,763) (22,380)
Wages Paid, Net of Amounts Capitalized (22,949) (17,985)
Payment of Other Operations and Maintenance Costs (32,983) (27,868)
Capital Lease Interest Paid (38,378) (40,304)
Taxes Paid, Net of Amounts Capitalized (14,325) (13,841)
Interest Paid, Net of Amounts Capitalized (24,059) (24,949)
Income Taxes Paid - (5,000)
Other Cash Payments (766) -
- -------------------------------------------------------------------------------------------------
NET CASH FLOWS - OPERATING ACTIVITIES 37,271 35,536
- -------------------------------------------------------------------------------------------------
CASH FLOWS FROM INVESTING ACTIVITIES
Capital Expenditures (33,513) (22,956)
Proceeds from Investment in Springerville Lease Debt and Equity 8,251 8,054
Payments for Investment in Springerville Lease Debt and Equity - (4,499)
Other Cash Receipts 5,000 -
- -------------------------------------------------------------------------------------------------
NET CASH FLOWS - INVESTING ACTIVITIES (20,262) (19,401)
- -------------------------------------------------------------------------------------------------
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Repayment of UniSource Energy Note 95,393 -
Repayments of Long-Term Debt (53,150) (1,225)
Payments on Capital Lease Obligations (48,357) (43,599)
Proceeds from Borrowings under Revolving Credit Facility - 20,000
Payments on Borrowings under Revolving Credit Facility - (20,000)
Other Cash Receipts 1,532 3,269
Payment of Debt Issue/Retirement Costs (122) (8,583)
Other Cash Payments (5,920) (423)
- -------------------------------------------------------------------------------------------------
NET CASH FLOWS - FINANCING ACTIVITIES (10,624) (50,561)
- -------------------------------------------------------------------------------------------------
Net Increase (Decrease) in Cash and Cash Equivalents 6,385 (34,426)
Cash and Cash Equivalents, Beginning of Year 113,207 65,262
- -------------------------------------------------------------------------------------------------
CASH AND CASH EQUIVALENTS, END OF PERIOD $ 119,592 $ 30,836
=================================================================================================
See Note 13 for supplemental cash flow information.
See Notes to Condensed Consolidated Financial Statements.
8
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED BALANCE SHEETS
March 31, December 31,
2005 2004
(UNAUDITED)
- -------------------------------------------------------------------------------------------------
ASSETS - Thousands of Dollars -
UTILITY PLANT
Plant in Service $ 2,793,624 $ 2,771,665
Utility Plant under Capital Leases 723,195 723,195
Construction Work in Progress 104,844 94,336
- -------------------------------------------------------------------------------------------------
TOTAL UTILITY PLANT 3,621,663 3,589,196
Less Accumulated Depreciation and Amortization (1,353,442) (1,328,228)
Less Accumulated Amortization of Capital Lease Assets (451,173) (444,186)
- -------------------------------------------------------------------------------------------------
TOTAL UTILITY PLANT - NET 1,817,048 1,816,782
- -------------------------------------------------------------------------------------------------
INVESTMENTS AND OTHER PROPERTY
Investments in Lease Debt and Equity 162,406 170,893
Other 23,284 23,393
- -------------------------------------------------------------------------------------------------
TOTAL INVESTMENTS AND OTHER PROPERTY 185,690 194,286
- -------------------------------------------------------------------------------------------------
NOTE RECEIVABLE FROM UNISOURCE ENERGY - 79,462
- -------------------------------------------------------------------------------------------------
CURRENT ASSETS
Cash and Cash Equivalents 119,592 113,207
Trade Accounts Receivable 67,719 72,042
Unbilled Accounts Receivable 23,061 33,179
Allowance for Doubtful Accounts (14,301) (14,166)
Intercompany Accounts Receivable 7,962 10,111
Materials and Fuel Inventory 54,580 51,207
Current Regulatory Assets 9,922 9,653
Income Taxes Receivable 6,972 -
Deferred Income Taxes - Current 15,030 24,157
Interest Receivable - Current 5,405 10,475
Other 15,895 18,330
- -------------------------------------------------------------------------------------------------
TOTAL CURRENT ASSETS 311,837 328,195
- -------------------------------------------------------------------------------------------------
REGULATORY AND OTHER ASSETS
Transition Recovery Asset 214,541 224,029
Income Taxes Recoverable Through Future Revenues 43,498 44,624
Other Regulatory Assets 14,103 13,684
Other Assets 42,728 41,106
- -------------------------------------------------------------------------------------------------
TOTAL REGULATORY AND OTHER ASSETS 314,870 323,443
- -------------------------------------------------------------------------------------------------
TOTAL ASSETS $ 2,629,445 $ 2,742,168
=================================================================================================
CAPITALIZATION AND OTHER LIABILITIES
CAPITALIZATION
Common Stock Equity $ 439,934 $ 414,510
Capital Lease Obligations 655,453 701,405
Long-Term Debt 1,046,170 1,097,595
- -------------------------------------------------------------------------------------------------
TOTAL CAPITALIZATION 2,141,557 2,213,510
- -------------------------------------------------------------------------------------------------
CURRENT LIABILITIES
Current Obligations under Capital Leases 56,143 53,611
Current Maturities of Long-Term Debt - 1,725
Accounts Payable 37,649 46,377
Intercompany Accounts Payable 9,816 20,026
Interest Accrued 24,406 56,514
Taxes Accrued 36,712 44,938
Accrued Employee Expenses 12,553 17,594
Other 12,015 9,592
- -------------------------------------------------------------------------------------------------
TOTAL CURRENT LIABILITIES 189,294 250,377
- -------------------------------------------------------------------------------------------------
DEFERRED CREDITS AND OTHER LIABILITIES
Deferred Income Taxes - Noncurrent 145,195 129,842
Regulatory Liability - Net Cost of Removal for Interim Retirements 69,306 67,485
Other 84,093 80,954
- -------------------------------------------------------------------------------------------------
TOTAL DEFERRED CREDITS AND OTHER LIABILITIES 298,594 278,281
- -------------------------------------------------------------------------------------------------
COMMITMENTS AND CONTINGENCIES (NOTE 6)
- -------------------------------------------------------------------------------------------------
TOTAL CAPITALIZATION AND OTHER LIABILITIES $ 2,629,445 $ 2,742,168
=================================================================================================
See Notes to Condensed Consolidated Financial Statements.
9
TUCSON ELECTRIC POWER COMPANY
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY
Accumulated
Capital Accumulated Other Total
Common Stock Earnings Comprehensive Stockholders'
Stock Expense (Deficit) Income (Loss) Equity
- ------------------------------------------------------------------------------------------------------------------------------------
(UNAUDITED)
- Thousands of Dollars -
BALANCES AT DECEMBER 31, 2004 $ 658,254 $ (6,357) $(226,652) $ (10,735) $ 414,510
- ------------------------------------------------------------------------------------------------------------------------------------
Comprehensive Income:
2005 Year-to-Date Net Loss - - (4,690) - (4,690)
Unrealized Gain on Cash Flow Hedges
(net of $2,315 income tax expense) - - - 3,531 3,531
Reclassification of Realized Gain on
Cash Flow Hedges to Net Income
(net of $48 income tax expense) - - - (73) (73)
----------------
Total Comprehensive Loss (1,232)
----------------
Equity Contribution from UniSource Energy (Note 3) 25,261 - - - 25,261
Capital Contribution from UniSource Energy 1,395 - - - 1,395
- ------------------------------------------------------------------------------------------------------------------------------------
BALANCES AT MARCH 31, 2005 $ 684,910 $ (6,357) $(231,342) $ (7,277) $ 439,934
====================================================================================================================================
See Notes to Condensed Consolidated Financial Statements.
10
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
- --------------------------------------------------------------------------------
NOTE 1. NATURE OF OPERATIONS, BASIS OF ACCOUNTING PRESENTATION AND EQUITY-BASED
COMPENSATION
UniSource Energy Corporation (UniSource Energy) is an exempt holding
company under the Public Utility Holding Company Act of 1935. UniSource Energy
has no significant operations of its own, but owns substantially all of the
common stock of Tucson Electric Power Company (TEP) and all of the common stock
of UniSource Energy Services, Inc. (UES), Millennium Energy Holdings, Inc.
(Millennium) and UniSource Energy Development Company (UED).
TEP, a regulated public utility incorporated in Arizona since 1963, is
UniSource Energy's largest operating subsidiary and represented approximately
84% of UniSource Energy's assets as of March 31, 2005. TEP generates, transmits
and distributes electricity. TEP serves approximately 378,000 retail electric
customers in a 1,155 square mile area in Southern Arizona. TEP also sells
electricity to other utilities and power marketing entities primarily located in
the western U.S.
UES holds the common stock of UNS Gas, Inc. (UNS Gas) and UNS Electric,
Inc. (UNS Electric). UES has no significant operations of its own. UNS Gas is a
gas distribution company serving approximately 135,600 retail customers in
Mohave, Yavapai, Coconino, and Navajo Counties in northern Arizona, as well as
Santa Cruz County in southeast Arizona. UNS Electric is an electric transmission
and distribution company serving approximately 86,500 retail customers in Mohave
and Santa Cruz counties.
Millennium invests in unregulated businesses, including Global Solar Energy
(Global Solar), a developer and manufacturer of thin-film photovoltaic cells and
modules. UED engages in developing generating resources and other project
development activities, including facilitating the expansion of the
Springerville Generating Station, but has no significant operations.
We conduct our business in four primary business segments - TEP's Electric
Utility segment, UNS Gas, UNS Electric and Global Solar.
References to "we" and "our" are to UniSource Energy and its subsidiaries,
collectively.
The accompanying quarterly financial statements of UniSource Energy and TEP
are unaudited but reflect all normal recurring accruals and other adjustments
which we believe are necessary for a fair presentation of the results for the
interim periods presented. These financial statements are presented in
accordance with the Securities and Exchange Commission's (SEC) interim reporting
requirements which do not include all the disclosures required by accounting
principles generally accepted in the United States of America (GAAP) for audited
annual financial statements. The year-end condensed balance sheet data was
derived from audited financial statements, but does not include disclosures
required by GAAP for audited annual financial statements. This quarterly report
should be reviewed in conjunction with UniSource Energy and TEP's 2004 Annual
Report on Form 10-K.
Weather, among other factors, causes seasonal fluctuations in TEP, UNS Gas
and UNS Electric's sales; therefore, quarterly results are not indicative of
annual operating results. UniSource Energy and TEP have made minor
reclassifications to the prior year financial statements for comparative
purposes. These reclassifications had no effect on net income.
EQUITY-BASED COMPENSATION
UniSource Energy has two equity-based compensation plans, the 1994 Outside
Director Stock Option Plan (Directors' Plan) and the 1994 Omnibus Stock and
Incentive Plan (Omnibus Plan). See Note 10. We early adopted Statement of
Financial Accounting Standards No. 123(R), Share Based Payment (FAS 123(R))
effective January 1, 2005. The adoption of FAS 123(R) did not have a significant
impact on our financial statements because stock options issued under UniSource
Energy's Omnibus Plan vested upon the shareholder vote to approve the proposed
acquisition of UniSource Energy, see UniSource Energy's 2004 Annual Report on
Form 10-K, Note 17 in Notes to Consolidated Financial Statements - Stock-Based
Compensation. In addition, no new stock options can be issued under the Omnibus
Plan after 2004. Prior to January 1, 2005, we accounted for those plans under
the recognition and measurement principles of APB Opinion No. 25, Accounting for
Stock Issued to Employees (APB 25), and related interpretations.
11
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
Prior to January 1, 2005, our stock options were granted with an exercise
price equal to the market value of the stock at the date of the grant.
Accordingly, under the provisions of APB 25 no compensation expense was recorded
for these awards. However, compensation expense was recognized for restricted
stock, stock unit and performance share awards over the performance/vesting
period.
The following table illustrates the effect on UniSource Energy's net income
and earnings per share and TEP's net income as if we had applied the fair value
recognition provisions of FAS 123(R) to all equity-based employee compensation
awards for the three months ended March 31, 2004:
UNISOURCE ENERGY:
- ----------------
Three Months Ended March 31,
- -------------------------------------------------------------------------------------------------------
2004
- -------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
(except per share data)
Net Income - As Reported $ 6,421
Add: Equity-based compensation expense included in reported net
income, net of related tax effects 1,243
Deduct: Total equity-based employee compensation expense
determined under fair value based method for all awards, net
of related tax effects (1,866)
- -------------------------------------------------------------------------------------------------------
Pro Forma Net Income $ 5,798
=======================================================================================================
Basic Earnings per Share:
As Reported $0.19
Pro Forma $0.17
=======================================================================================================
Diluted Earnings per Share:
As Reported $0.18
Pro Forma $0.17
=======================================================================================================
TEP:
- ----
Three Months Ended March 31,
- -------------------------------------------------------------------------------------------------------
2004
- -------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
Net Income - As Reported $ 794
Add: Equity-based compensation expense included in reported net
income, net of related tax effects 1,119
Deduct: Total equity-based employee compensation expense
determined under fair value based method for all awards, net
of related tax effects (1,730)
- -------------------------------------------------------------------------------------------------------
Pro Forma Net Income $ 183
=======================================================================================================
The fair value of each stock option grant is estimated on the date of grant
using the Black-Scholes option-pricing model. There were no stock options
granted in the first quarter of 2004. For the 21,222 options granted under the
Directors' Plan in 2003, the following weighted average assumptions were used:
2003
- -------------------------------------------------------------------------------------------------------
Expected life (years) 6
Interest rate 3.34%
Volatility 23.74%
Dividend yield 3.55%
Weighted-average grant-date fair value of options
granted during the period $3.16
- -------------------------------------------------------------------------------------------------------
12
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
NOTE 2. REGULATORY MATTERS
- ---------------------------
REGULATORY ACCOUNTING
TEP, UNS Gas and UNS Electric generally use the same accounting policies
and practices used by unregulated companies for financial reporting under GAAP.
However, sometimes these principles, such as Statement of Financial Accounting
Standards No. 71, Accounting for the Effects of Certain Types of Regulation (FAS
71), require special accounting treatment for regulated companies to show the
effect of regulation. For example, in setting TEP, UNS Gas and UNS Electric's
retail rates, the Arizona Corporation Commission (ACC) may not allow TEP, UNS
Gas or UNS Electric to currently charge their customers to recover certain
expenses, but instead requires that these expenses be charged to customers in
the future. In this situation, FAS 71 requires that TEP and UES defer these
items and show them as regulatory assets on the balance sheet until TEP, UNS Gas
and UNS Electric are allowed to charge their customers. TEP, UNS Gas and UNS
Electric then amortize these items as expense to the income statement as these
charges are recovered from customers. Similarly, certain revenue items may be
deferred as regulatory liabilities, which are also eventually amortized to the
income statement as rates to customers are reduced.
The conditions a regulated company must satisfy to apply the accounting
policies and practices of FAS 71 include:
o an independent regulator sets rates;
o the regulator sets the rates to recover specific costs of delivering
service; and
o the service territory lacks competitive pressures to reduce rates
below the rates set by the regulator.
IMPLICATIONS OF DISCONTINUING APPLICATION OF FAS 71
TEP
Upon approval by the ACC of a settlement agreement (TEP Settlement
Agreement) in November 1999, TEP discontinued application of FAS 71 for its
generation operations. TEP continues to apply FAS 71 to its regulated
operations, which include the transmission and distribution portions of its
business.
TEP's transmission and distribution regulatory assets, net of regulatory
liabilities, totaled $213 million at March 31, 2005. Regulatory assets of $24
million are not presently included in rate base and consequently are not earning
a return on investment. TEP's transmission and distribution regulatory assets,
net of regulatory liabilities, totaled $225 million at December 31, 2004.
TEP regularly assesses whether it can continue to apply FAS 71 to its
regulated operations. If TEP stopped applying FAS 71 to these operations, it
would write off the related balances of its regulatory assets as an expense and
its regulatory liabilities as income on its income statement. Based on the
regulatory asset balances, net of regulatory liabilities, at March 31, 2005, if
TEP had stopped applying FAS 71 to its remaining regulated operations, it would
have recorded an extraordinary after-tax loss of $129 million. While regulatory
orders and market conditions may affect cash flows, TEP's cash flows would not
be affected if it stopped applying FAS 71 unless a regulatory order limited its
ability to recover the cost of its regulatory assets.
UNS GAS AND UNS ELECTRIC
UNS Gas and UNS Electric's regulatory liabilities exceed their regulatory
assets by $5 million at March 31, 2005. At December 31, 2004, UNS Gas and UNS
Electric's regulatory assets, net of regulatory liabilities, totaled $4 million.
UNS Gas and UNS Electric's regulatory assets and liabilities are included in
rate base and consequently are earning a return on investment. If UNS Gas and
UNS Electric stopped applying FAS 71 to their regulated operations, they would
write off the related balances of their regulatory assets as an expense and
would write off their regulatory liabilities as income on their income
statements. Based on the regulatory asset and liability balances, if UNS Gas and
UNS Electric had stopped applying FAS 71 to their regulated operations, they
would have recorded an extraordinary after-tax gain of $3 million at March 31,
2005. UNS Gas and UNS Electric's cash flows would not be affected if they
stopped applying FAS 71 unless a regulatory order limited their ability to
recover the cost of their regulatory assets.
13
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
RECENT REGULATORY ACTION
TEP
Given recent court action, the ACC may revise its Rules and rate
methodologies prior to the expiration in 2008 of the TEP Settlement Agreement. A
new structure could replace that established pursuant to the TEP Settlement
Agreement prior to January 2009.
In an effort to resolve the uncertainty surrounding the continued
applicability of the Rules and the methodology that will be applied to determine
TEP's rates for generation service after the CTCs expire, TEP filed a motion
with the ACC on May 4, 2005 requesting that the ACC issue an order declaring its
position regarding the status of the Rules and the rate treatment that will be
afforded to TEP's generation assets after 2008.
The motion states TEP's preference for the ACC to adhere to the 1999
Settlement Agreement and continue to authorize TEP to charge market-based rates
for generation services after December 31, 2008. The motion also states that, if
the ACC intends to rescind TEP's authorization to charge market-based rates for
its generation services, that change will have immediate consequences for the
Settlement Agreement, the 2004 general rate case information filing and future
TEP rate cases. Accordingly, TEP requested that the ACC clarify its intentions
in this regard. In addition, TEP requested that a procedural conference be held
in the 2004 rate review proceedings to discuss the status of that case pending
the issuance of an order in response to TEP's motion. TEP cannot predict when,
or how, the ACC will respond to the motion.
UES
In January 2005, UNS Gas requested the ACC approve a PGA surcharge of $0.06
per therm beginning April 1, 2005 and removed one year later, to recover its
excess gas purchase costs. The previous PGA surcharge of $0.1155 per therm took
effect October 1, 2003 and ended November 1, 2004. On March 31, 2005, the ACC
approved a PGA surcharge of $0.03 per therm beginning April 11, 2005 and lasting
until the excess gas purchase costs are fully recovered. Based on the rates
currently in effect, we do not expect the PGA balance to be fully recovered
until 2008. The under recovered gas purchase costs of $2.3 million as of March
31, 2005, are recorded in Other Regulatory Assets on UniSource Energy's balance
sheet.
NOTE 3. DEBT AND CREDIT FACILITIES
- -----------------------------------
Long-term debt matures more than one year from the date of the financial
statements.
UNISOURCE ENERGY DEBT
CONVERTIBLE SENIOR NOTES
On March 1, 2005, UniSource Energy issued $150 million aggregate principal
amount of 4.50% Convertible Senior Notes (Convertible Senior Notes) due 2035 in
a private placement. The Convertible Senior Notes are unsecured. Each $1,000
principal amount of Convertible Senior Notes is convertible into 26.6667 shares
of UniSource Energy Common Stock at any time, representing a conversion price of
approximately $37.50 per share of our Common Stock, subject to adjustment in
certain circumstances.
The Convertible Senior Notes bear interest at an annual rate of 4.50%
payable semi-annually in arrears on each March 1 and September 1, commencing on
September 1, 2005. In addition, beginning on March 1, 2015, the Convertible
Senior Notes will also, in certain circumstances, bear contingent interest at
the annual rate of 0.35%.
Beginning on March 5, 2010, we will have the option to redeem the
Convertible Senior Notes, in whole or in part, for cash, at a price equal to
100% of the principal amount plus accrued interest. If certain change of control
transactions occur, or our common stock is no longer listed on a national
securities exchange, holders of the Convertible Senior Notes may require
UniSource Energy to repurchase the Convertible Senior Notes, in whole or in
14
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
part, for cash. If one of these events occurs prior to March 5, 2010, we may be
required to pay a make-whole premium payable in shares of common stock.
Additionally, the holders of the Convertible Senior Notes may require us to
repurchase for cash, all or part, of the Convertible Senior Notes on March 1,
2015, 2020, 2025 and 2030. The repurchase price will be 100% of the principal
amount of the Convertible Senior Notes plus accrued interest.
The Convertible Senior Notes may become immediately payable if an event of
default occurs. An event of default includes failure to make required payments
on the Convertible Senior Notes, acceleration of $50 million or more of
indebtedness for borrowed money at UniSource Energy or TEP or certain bankruptcy
events at UniSource Energy or TEP. Neither TEP nor any other subsidiary of
UniSource Energy has guaranteed UniSource Energy's obligations on the
Convertible Senior Notes.
On March 1, 2005, UniSource Energy used $106 million of the net proceeds
from the sale of the Convertible Senior Notes to repay its $95 million
promissory note to TEP plus accrued interest of $11 million. See Inter-Company
Notes Payable, below. TEP will use these funds to retire or repurchase $225
million of its outstanding debt obligations. See TEP Debt - Bond Repurchase and
Redemptions, below.
UNISOURCE CREDIT AGREEMENT
On April 15, 2005, UniSource Energy entered into a $105 million five-year
credit agreement with a group of lenders (UniSource Credit Agreement) which
expires on April 15, 2010. The UniSource Credit Agreement includes a $90 million
term loan facility and a $15 million revolving credit facility. In addition,
UniSource Energy is required to make quarterly payments of $1.25 million
beginning June 2005 with the balance due at maturity.
Interest is payable on borrowings under the UniSource Credit Agreement at a
Eurodollar rate or Alternate Base Rate rate. Eurodollar loans would bear
interest at adjusted LIBOR plus 1.75%. Alternate Base Rate loans would bear
interest in an amount equal to the sum of (1) the greater of the federal funds
rate plus 1/2 of 1% or the agent bank's reference rate, and (2) 0.75%. In the
event that, after June 30, 2005, TEP, because of regulatory restrictions, does
not have the ability to pay 100% of its current year net income as dividends,
interest rates would increase by 0.25%.
The UniSource Credit Agreement contains a number of covenants restricting
additional indebtedness, liens, mergers, sales of assets and investments and
acquisitions. Additionally, the UniSource Credit Agreement contains several
financial covenants including: (1) a minimum cash flow to interest coverage
ratio determined on a UniSource Energy standalone basis and (2) a maximum
leverage ratio determined on a consolidated basis. The UniSource Credit
Agreement allows UniSource Energy to pay dividends, if after giving effect to
the dividend payment, UniSource Energy and it subsidiaries have more than $15
million of unrestricted cash and unused revolving credit.
The UniSource Credit Agreement may become immediately payable if an event
of default occurs. An event of default includes failure to make required
payments under the UniSource Credit Agreement, failure of UniSource Energy or
certain subsidiaries to make payments or default on debt greater than $20
million, or certain bankruptcy events at UniSource Energy or certain
subsidiaries. The UniSource Credit Agreement is collateralized by a pledge of
the capital stock of Millennium, UES and UED.
INTER-COMPANY NOTES PAYABLE
In January 2005, UNS Gas established a short-term inter-company promissory
note to UniSource Energy, by allowing UNS Gas to borrow up to $10 million for
general corporate purposes. In March 2005, UniSource Energy contributed an
additional $6 million in equity to UNS Gas and an additional $4 million in
equity to UNS Electric, and UNS Gas repaid the $6 million outstanding on this
note from the proceeds of the $6 million equity contribution.
On January 1, 1998, TEP and UniSource Energy exchanged all the outstanding
common stock of TEP on a share-for-share basis for the Common Stock of UniSource
Energy in a transaction which resulted in UniSource Energy becoming a holding
company with TEP as its subsidiary. Following the share exchange, TEP
transferred the stock of Millennium to UniSource Energy for a $95 million
promissory note due in 2008. On March 1, 2005, UniSource Energy used $106
million of the $146 million of net proceeds from the convertible debt offering,
see above, to repay the $95 million promissory note to TEP plus accrued interest
of $11 million. Approximately $25 million of this note represented a gain to
15
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
TEP. TEP did not record this gain in income. Instead, this gain was reflected as
an increase in TEP's common stock equity when UniSource Energy repaid the note.
TEP DEBT
BOND REPURCHASE AND REDEMPTIONS
TEP made the required sinking fund payment of $1 million on its 6.1% First
Mortgage IDBs in January 2005. In March 2005, TEP redeemed at par the remaining
$31 million of its 6.1% First Mortgage IDBs, which were due in 2008, as well as
the remaining $21 million of its 7.5% First Mortgage IDBs, which were due in
2006.
As stated in a recently expired tender offer, TEP has agreed to purchase
$147 million of its 1997 Pima Series B and $74 million of its 1997 Pima Series C
fixed-rate tax-exempt debt obligations (Repurchased Bonds) from bondholders on
May 11, 2005, at a price of $101.50 per $100 principal amount. Additionally, TEP
will redeem at par $4 million of bonds not tendered on May 18, 2005. TEP does
not plan on canceling the Repurchased Bonds. The Repurchased Bonds will remain
outstanding under their respective indentures; however, the Repurchased Bonds
will not be presented in our financial statements. TEP may choose to cancel or
resell the Repurchased Bonds to third parties in the future.
TEP CREDIT AGREEMENT
On May 4, 2005, TEP entered into a new $401 million Credit Agreement (TEP
Credit Agreement) to replace its previous $401 million credit agreement. The TEP
Credit Agreement includes a $60 million revolving credit facility and a $341
million letter of credit facility to support $329 million aggregate principal
amount of tax-exempt variable rate bonds. The TEP Credit Agreement expires May
4, 2010 and is secured by $401 million of Second Mortgage Bonds.
Covenants in the TEP Credit Agreement restrict additional indebtedness,
liens and sale of assets and sale-leasebacks agreements. The TEP Credit
Agreement also contains several financial covenants including: (1) a minimum
cash coverage ratio, and (2) a maximum leverage ratio. If TEP complies with the
terms of the TEP Credit Agreement, TEP may pay dividends to UniSource Energy.
Certain regulatory actions may cause a decrease in the amount that may be
borrowed.
The TEP Credit Agreement may become immediately due and payable if an event
of default occurs. An event of default includes failure to make required
payments under the TEP Credit Agreement; change in control, as defined; failure
of TEP or certain subsidiaries to make payments or default on debt greater than
$20 million; or certain bankruptcy events at TEP.
Interest rates and fees under the TEP Credit Agreement are based on a
pricing grid tied to TEP's credit ratings. The letter of credit fees are 0.875%
under the TEP Credit Agreement. Amounts drawn under the letter of credit would
currently bear interest based on LIBOR plus 0.875% per annum. Borrowings under
the revolving credit facility bear interest at a variable interest consisting of
a spread over LIBOR or an alternate base rate. The per annum rate currently in
effect on borrowings under TEP's revolving credit facility is LIBOR plus 0.875%.
TEP also pays a commitment fee of 0.20% on the unused portion of the revolving
credit facility.
At May 6, 2005, TEP had no outstanding borrowings under the revolving
credit facility component of the TEP Credit Agreement.
UNS GAS/UNS ELECTRIC REVOLVER
On April 15, 2005, UNS Gas and UNS Electric, each as a borrower, and UES,
as guarantor, entered into a $40 million three-year unsecured revolving credit
agreement with a group of lenders (the UNS Gas/UNS Electric Revolver). Either
borrower may borrow up to a maximum of $30 million; however, the total combined
amount borrowed can not exceed $40 million. The UNS Gas/UNS Electric Revolver
expires on April 15, 2008.
UNS Gas is only liable for UNS Gas' borrowings, and similarly, UNS Electric
is only liable for UNS Electric's borrowings under the UNS Gas/UNS Electric
Revolver. UES guarantees the obligations of both UNS Gas and UNS Electric.
16
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
Interest is payable at LIBOR plus 1.50%; or at a rate equal to the sum of:
(1) the greater of the federal funds rate plus 1/2 of 1% or a bank reference
rate, and (2) 0.50%.
The UNS Gas/UNS Electric Revolver contains a number of covenants which
restrict additional indebtedness, liens, mergers and sales of assets. The UNS
Gas/UNS Electric Revolver also contains several financial covenants including:
(1) a maximum consolidated leverage ratio and (2) a minimum cash flow to
interest coverage ratio, in each case determined for each borrower on a
standalone basis.
The UNS Gas/UNS Electric Revolver may become immediately due and payable if
an event of default occurs. An event of default includes failure to make
required payments under the UNS Gas/UNS Electric Revolver; a change in control,
as defined, or certain bankruptcy events of UNS Gas or UNS Electric; or failure
of UES, UNS Gas or UNS Electric to make payments or default on debt greater than
$4 million.
NOTE 4. BUSINESS SEGMENTS
- --------------------------
Based on the way we organize our operations and evaluate performance, we
have four reportable segments:
(1) TEP, a vertically integrated electric utility business, is UniSource
Energy's largest subsidiary.
(2) UNS Gas is a regulated gas distribution business.
(3) UNS Electric is a regulated electric distribution utility business.
(4) Global Solar, a developer and manufacturer of light-weight thin-film
photovoltaic cells and panels, is the largest investment held by
Millennium.
The UniSource Energy, UES and Millennium holding companies, UED, and
several other subsidiaries and equity investments, which are not considered
reportable segments, are included in All Other. Through affiliates, Millennium
holds investments in several unregulated energy and emerging technology
companies. UED, a wholly-owned subsidiary of UniSource Energy, developed
generating resources and performed other project development activities,
including the expansion of the Springerville Generating Station.
Our reportable segments have changed from the segments reported in prior
years. We have reclassified information for earlier periods to conform to the
current year's presentation.
Significant reconciling adjustments consist of the elimination of
inter-company activity and balances. Other Millennium subsidiaries recorded
revenue from transactions with TEP of $3 million during each of the three-month
periods ended March 31, 2005 and March 31, 2004. TEP's related expense is
reported in Other Operations and Maintenance expense on its income statement.
Millennium's revenue and TEP's related expense are eliminated in UniSource
Energy consolidation. Other significant reconciling adjustments include the
elimination of investments in subsidiaries held by UniSource Energy, the
inter-company note between UniSource Energy and TEP, the related interest income
and expense on the note and reclassifications of deferred tax assets and
liabilities. The inter-company note between UniSource Energy and TEP was repaid
on March 1, 2005. See Note 3.
We record our percentage share of the earnings of affiliated companies when
we hold a 20% to 50% voting interest, except for investments where we provide
all of the financing, in which case we recognize 100% of the losses.
17
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
We disclose selected financial data for our reportable segments in the
following table:
REPORTABLE SEGMENTS
----------------------------------------- UNISOURCE
UNS UNS GLOBAL ALL RECONCILING ENERGY
TEP GAS ELECTRIC SOLAR OTHER ADJUSTMENTS CONSOLIDATED
- ------------------------------------------------------------------------------------------------------------------------------------
INCOME STATEMENT -Millions of Dollars-
- ------------------------------------------------------------------------------------------------------------------------------------
THREE MONTHS ENDED MARCH 31, 2005:
- ------------------------------------------------------------------------------------------------------------------------------------
Operating Revenues - External $ 181 $ 47 $ 32 $ - $ 1 $ - $ 261
- ------------------------------------------------------------------------------------------------------------------------------------
Operating Revenues - Intersegment 1 - - - 3 (4) -
- ------------------------------------------------------------------------------------------------------------------------------------
Income (Loss) Before Income Taxes (7) 7 1 (3) (3) - (5)
- ------------------------------------------------------------------------------------------------------------------------------------
Net Income (Loss) (5) 4 1 (2) (2) - (4)
- ------------------------------------------------------------------------------------------------------------------------------------
- ------------------------------------------------------------------------------------------------------------------------------------
THREE MONTHS ENDED MARCH 31, 2004:
Operating Revenues - External $ 187 $ 49 $ 31 $ 1 $ 2 $ - $ 270
- ------------------------------------------------------------------------------------------------------------------------------------
Operating Revenues - Intersegment - - - - 3 (3) -
- ------------------------------------------------------------------------------------------------------------------------------------
Income (Loss) Before Income Taxes 3 7 1 (2) 3 - 12
- ------------------------------------------------------------------------------------------------------------------------------------
Net Income (Loss) 1 4 1 (1) 1 - 6
- ------------------------------------------------------------------------------------------------------------------------------------
- ------------------------------------------------------------------------------------------------------------------------------------
BALANCE SHEET
- ------------------------------------------------------------------------------------------------------------------------------------
Total Assets, March 31, 2005 $ 2,629 $ 204 $ 139 $ 21 $ 843 $ (683) $ 3,153
- ------------------------------------------------------------------------------------------------------------------------------------
Total Assets, December 31, 2004 2,742 201 135 21 930 (853) 3,176
- ------------------------------------------------------------------------------------------------------------------------------------
NOTE 5. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND TRADING ACTIVITIES
- ---------------------------------------------------------------------
TEP enters into forward contracts to purchase or sell a specified amount of
capacity or energy at a specified price over a given period of time, typically
for one month, three months, or one year, within established limits to take
advantage of favorable market opportunities. In general, TEP enters into forward
purchase contracts when market conditions provide the opportunity to purchase
energy for its load at prices that are below the marginal cost of its supply
resources or to supplement its own resources (e.g., during plant outages and
summer peaking periods). TEP enters into forward sales contracts when it
forecasts that it has excess supply and the market price of energy exceeds its
marginal cost. The majority of TEP's forward contracts are considered to be
normal purchases and sales and, therefore, are not required to be marked to
market. However, some of these forward contracts are considered to be
derivatives, which TEP marks to market by recording unrealized gains and losses
and adjusting the related assets and liabilities on a monthly basis to reflect
the market prices at the end of the month.
TEP has a natural gas supply agreement under which it purchases all of its
gas requirements at spot market prices from Southwest Gas Corporation (SWG). TEP
also has agreements to purchase power that are priced using spot market gas
prices. These contracts meet the definition of normal purchases and are not
required to be marked to market. During 2004 and early 2005, in an effort to
minimize price risk on these purchases, TEP entered into commodity price swap
agreements under which TEP purchases gas at fixed prices and simultaneously
sells gas at spot market prices. The spot market price in the swap agreements is
tied to the same index as the purchases under the SWG and purchased power
contracts. These swap agreements, which expire during the summer months through
2007, were entered into with the goal of locking in fixed prices on at least 45%
and not more than 80% of TEP's expected summer monthly gas risk prior to
entering into the month. TEP's swap agreements are marked to market on a monthly
basis; however, since the agreements satisfy the requirements for cash flow
hedge accounting, the unrealized gains and losses are recorded in Other
Comprehensive Income, a component of Common Stock Equity, rather than being
reflected in the income statement. As the gains and losses on these cash flow
hedges are realized, a reclassification adjustment is recorded in Other
Comprehensive Income for realized gains and losses that are included in Net
Income.
TEP manages the risk of counterparty default by performing financial credit
reviews, setting limits, monitoring exposures, requiring collateral when needed,
and using a standardized agreement which allows for the netting of current
period exposures to and from a single counterparty.
UNS Gas and UNS Electric do not currently have any contracts that are
required to be marked to market. UNS Gas does have a natural gas supply and
management agreement under which it purchases substantially all of its gas
18
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
requirements at market prices from BP Energy Company (BP). However, the contract
terms allow UNS Gas to lock in fixed prices on a portion of its gas purchases by
entering into fixed price forward contracts with BP at various times during the
year. This enables UNS Gas to provide more stable prices to its customers. These
purchases are made up to three years in advance with the goal of locking in
fixed prices on at least 45% and not more than 80% of the expected monthly gas
consumption prior to entering into the month. These forward contracts, as well
as the main gas supply contract, meet the definition of normal purchases and
therefore are not required to be marked to market.
Millenium Environmental Group, Inc. (MEG), a wholly-owned subsidiary of
Millennium, enters into swap agreements, options and forward contracts relating
to Emissions Allowances and coal. MEG marks its trading contracts to market by
recording unrealized gains and losses and adjusting the related assets and
liabilities on a monthly basis to reflect the market prices at the end of the
month.
The market prices used to determine fair values for TEP and MEG's
derivative instruments are estimated based on various factors including broker
quotes, exchange prices, over the counter prices and time value.
TEP and MEG's derivative activities are reported as follows:
INCOME STATEMENT LINE
------------------------------------------------------------------------
NET UNREALIZED GAINS NET REALIZED GAINS
AND LOSSES AND LOSSES
- ---------------------------------------------------------------------------------------------------------------------
TEP Forward Sales Contracts Electric Wholesale Sales Electric Wholesale Sales
TEP Forward Purchase Contracts Purchased Power Purchased Power
TEP Commodity Price Swaps Other Comprehensive Income Fuel Expense
(Balance Sheet)
MEG Trading Activities Other Operating Revenues Other Operating Revenues
- ---------------------------------------------------------------------------------------------------------------------
Although MEG's realized gains and losses on trading activities are reported
net on UniSource Energy's income statement, the related cash receipts and cash
payments are reported separately on UniSource Energy's statement of cash flows.
The net pre-tax gains and losses from TEP and MEG's derivative activities
were as follows:
Three Months Ended
March 31,
-----------------------------------
2005 2004
- ---------------------------------------------------------------------------------------------------------------------
-Millions of Dollars-
TEP:
Net Unrealized (Loss) Gain on Forward Sales Contracts $ (0.8) $ 0.5
Net Unrealized Gain (Loss) on Forward Purchase Contracts 1.2 (0.3)
Net Unrealized Gain on Commodity Price Swaps 5.7 1.5
Net Realized Gain on Commodity Price Swaps 0.1 -
MEG:
Net Gain from Trading Activities 0.3 0.2
- ---------------------------------------------------------------------------- ------------------ ----------------
TEP and MEG's derivative assets and liabilities are reported as follows:
BALANCE SHEET LINE
-----------------------------------------------------
ASSETS LIABILITIES
- ---------------------------------------------------------------------------------------------------------------------
TEP - Current Other Current Assets Other Current Liabilities
TEP - Noncurrent Other Assets Other Liabilities
MEG - Current (including Emissions Allowance Inventory) Trading Assets Trading Liabilities
MEG - Noncurrent Other Assets Other Liabilities
- ---------------------------------------------------------------------------------------------------------------------
19
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
The fair value of TEP and MEG's derivative assets and liabilities were as
follows:
March 31, December 31,
2005 2004
- --------------------------------------------------------------------------------
-Millions of Dollars-
TEP:
Derivative Assets - Current $ 5.7 $ 2.3
Derivative Assets - Noncurrent 4.2 1.3
Derivative Liabilities - Current - (0.1)
MEG:
Trading Assets - Current 50.8 71.0
Trading Assets - Noncurrent 5.6 5.5
Trading Liabilities - Current (51.0) (65.0)
- --------------------------------------------------------------------------------
Beginning January 1, 2004, the settlement of forward purchase and sales
contracts that do not result in physical delivery are recorded net as a
component of Electric Wholesale Sales in TEP's income statement. For the three
months ended March 31, 2005, $5 million in sales were netted against $4 million
in purchases and for the three months ended March 31, 2004, $1 million in sales
were netted against $1 million in purchases.
In accordance with UniSource Energy's intention to cease making capital
contributions to Millennium, Millennium has significantly reduced the holdings
and activity of MEG. MEG is in the process of winding down its activities and
will not engage in any new activities after 2005.
NOTE 6. COMMITMENTS AND CONTINGENCIES
- --------------------------------------
TEP CONTINGENCIES
SPRINGERVILLE GENERATING STATION COMPLAINT
Environmental activist groups have expressed concerns regarding the
construction of any new units at the Springerville Generating Station. In
January 2003, environmental activist groups appealed an ACC Order affirming the
ACC's approval of the expansion at the Springerville Generating Station to the
Superior Court of the State of Arizona. On October 22, 2003, the Superior Court
affirmed the ACC's issuance of the Certificate of Environmental Compatibility
for Springerville Generating Station. The environmental activist groups appealed
the Superior Court decision on December 30, 2003 and filed an amended notice of
appeal on January 2, 2004 with the Arizona Court of Appeals. In February 2005,
the Arizona Court of Appeals upheld the lower court's ruling affirming the ACC's
approval of the expansion at Springerville Generating Station. The Grand Canyon
Trust (GCT), one of the environmental activist groups with this appeal, agreed
to resolve this claim against TEP. The other environmental activist group
petitioned the Arizona Supreme Court for review on March 24, 2005.
LITIGATION AND CLAIMS RELATED TO SAN JUAN GENERATING STATION
The Environmental Protection Agency (EPA) has listed San Juan as a
potential damage case pursuant to the Resource Conservation and Recovery Act due
to claims by third parties that the San Juan Generating Station has contaminated
water resources in the region as a result of disposing of fly ash in the surface
mine pits adjacent to the generating station. Public Service Company of New
Mexico (PNM), operator of San Juan, and the coal supplier to San Juan vigorously
deny these allegations. In November 2004, a contractor for the EPA determined
that any contamination at San Juan cannot be conclusively attributed to the
disposal of fly ash, however, the EPA has not made a final determination. TEP
owns 50% of San Juan Units 1 and 2, which equates to 19.8% of the total San Juan
Generating Station. TEP does not believe that this issue will have a material
adverse impact on TEP or its operations.
LITIGATION AND CLAIMS RELATED TO NAVAJO GENERATING STATION
On October 15, 2004, Peabody Western Coal Company (Peabody), the coal
supplier to the Navajo Generating Station, filed a complaint in the Circuit
Court for the City of St. Louis, Missouri against the participants at Navajo,
including TEP, for reimbursement of royalties and other costs and breach of the
coal supply agreement. The case was removed to Federal District Court Eastern
District of Missouri on February 10, 2005. Peabody subsequently filed a motion
20
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
to remand to superior court. Because TEP owns 7.5% of the Navajo Generating
Station, its share of the current claimed damages would be approximately $35
million. TEP believes these claims are without merit and intends to continue to
contest them.
POSTRETIREMENT AND PENSION BENEFIT COSTS AT NAVAJO GENERATING STATION
Peabody has filed a lawsuit against the participants at Navajo Generating
Station, including TEP, for postretirement benefit costs payable to the coal
supplier's employees under the coal supply agreements. The Navajo participants
and Peabody have agreed to stay the discovery process in this litigation until
August 31, 2005 to allow the parties additional time to negotiate a potential
settlement. To the extent that amounts become estimable and payment probable,
TEP will record a liability for additional postretirement benefit costs at the
Navajo Generating Station. TEP does not expect any settlement to be material to
TEP.
TEP has previously settled claims for postretirement benefit costs with the
coal suppliers at Springerville Generating Station and Four Corners Generating
Station. The cost of postretirement benefits is included in the cost of coal to
San Juan.
ENVIRONMENTAL RECLAMATION AT REMOTE GENERATING STATIONS
TEP currently pays on-going reclamation costs related to the coal mines
which supply the remote generating stations, and it is probable that TEP will
have to pay a portion of final reclamation costs upon mine closure. When a
reasonable estimate of final reclamation costs is available, the liability is
recognized as a cost of coal over the remaining term of the respective coal
supply agreement. At March 31, 2005, TEP estimates its undiscounted final
reclamation liability to be $42 million, and the present value of TEP's
liability for final reclamation approximates $12 million at the expiration dates
of the coal supply agreements.
Amounts recorded for final reclamation are subject to various assumptions
and determinations, such as estimating the costs of reclamation, estimating when
final reclamation will occur, and the credit-adjusted risk-free interest rate to
be used to discount future liabilities. Changes that may arise over time with
regard to these assumptions and determinations will change amounts recorded in
the future as expense for post-term reclamation. TEP does not believe that
recognition of its final reclamation obligations will be material to TEP in any
single year since recognition occurs over the remaining lives of its coal supply
agreements.
MILLENNIUM CONTINGENCY - NATIONS ENERGY
In September 2001, Nations Energy sold its 26% equity interest in a power
project located in Curacao, Netherlands Antilles to Mirant Curacao Investments,
Ltd. (Mirant Curacao) a subsidiary of Mirant Corporation (Mirant). Nations
Energy received $5 million in cash and an $11 million note receivable from
Mirant Curacao. The note was recorded at its net present value of $8 million
using an 8% discount rate, the discount being recognized as interest income over
the five-year life of the note. As of March 31, 2005, Nations Energy's
receivable from Mirant Curacao is approximately $8 million. The note is
primarily included in Investments and Other Property - Other on UniSource
Energy's balance sheet. The first payment of $2 million on the receivable was
received in June 2004. The remaining payments on the note receivable are
expected to be received as follows: $4 million in July 2005 and $5 million in
July 2006.
The note is guaranteed by Mirant Americas, Inc., a subsidiary of Mirant. On
July 14, 2003, Mirant, Mirant Americas, Inc. and various other Mirant companies
filed for Chapter 11 bankruptcy protection. Mirant Curacao was not included in
the Chapter 11 filings. Based on a review of the projected cash flows for the
power project, it appears Mirant Curacao will have sufficient future cash flows
to pay the note receivable and any applicable interest. However, we cannot
predict the ultimate outcome that Mirant's bankruptcy will have on the
collectibility of the note from Mirant Curacao. Nations Energy will continue to
evaluate the collectibility of the receivable, but currently expects to collect
the note in its entirety and has not recorded any reserve for this note.
MILLENNIUM COMMITMENT
In April 2005, Millennium committed to fund $3 million to an investment of
Infinite Power Solutions, Inc. (IPS).
21
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
GUARANTEES AND INDEMNITIES
In the normal course of business, UniSource Energy and certain subsidiaries
enter into various agreements providing financial or performance assurance to
third parties on behalf of certain subsidiaries. We enter into these agreements
primarily to support or enhance the creditworthiness of a subsidiary on a
stand-alone basis. The most significant of these guarantees are:
o UES' guarantee of $160 million of aggregate principal amount of senior
unsecured notes issued by UNS Gas and UNS Electric to purchase the
Citizens Arizona gas and electric utility assets,
o UES' guarantee of a $40 million unsecured revolving credit agreement
for UNS Gas and UNS Electric,
o UniSource Energy's guarantee of approximately $8 million in natural
gas transportation and supply payments in addition to building and
equipment lease payments for UNS Gas, UNS Electric, and subsidiaries
of Millennium, and
o Millennium's guarantee of approximately $3 million in
commodity-related payments for MEG and building lease payments for a
subsidiary.
In addition, UniSource Energy and its subsidiaries have indemnified the
purchasers of interests in certain investments from additional taxes due for
years prior to the sale of such investments. The terms of the indemnifications
provide for no limitation on potential future payments; however, we believe that
we have abided by all tax laws and paid all tax obligations. We have not made
any payments under the terms of these indemnifications to date.
We believe that the likelihood UniSource Energy, UES, or Millennium would
be required to perform or otherwise incur any significant losses associated with
any of these guarantees or indemnities is remote.
NOTE 7. TEP WHOLESALE ACCOUNTS RECEIVABLE AND ALLOWANCES
- ---------------------------------------------------------
TEP's Accounts Receivable from Electric Wholesale Sales, included in Trade
Accounts Receivable on the balance sheet, totaled $21 million at March 31, 2005
and $22 million at December 31, 2004, net of allowances. TEP's Allowance for
Doubtful Accounts on the balance sheet includes $13 million at March 31, 2005
and $13 million at December 31, 2004 related to sales to the California Power
Exchange (CPX) and the California Independent System Operator (CISO) in 2001 and
2000. Excluding the receivables from the CPX and the CISO, substantially all of
the December 31, 2004 wholesale receivable balance has been collected as of the
date of this filing.
TEP's collection shortfall from the CPX and the CISO was approximately $9
million for sales made in 2000 and $7 million for sales made in 2001. Since that
time, the FERC staff has proposed various methodologies for calculating amounts
of refunds/offsets applicable to wholesale sales made into the CISO's spot
markets from October 2000 to June 2001. Based upon a FERC order in March 2003
(as reaffirmed by the FERC on October 16, 2003), TEP estimated that it would
receive approximately $6 million of its $16 million receivable. In May 2004, the
FERC issued two separate orders addressing numerous issues in the refund
calculation and the fuel cost allowance calculation (an offset to the refund
obligation). Based on these new orders, TEP increased its reserve for sales to
the CPX and the CISO by $3 million by recording a reduction of wholesale
revenues.
There are several other outstanding legal issues, complaints and lawsuits
concerning the California energy crisis related to the FERC, wholesale power
suppliers, Southern California Edison Company, Pacific Gas and Electric Company,
the CPX and the CISO. We cannot predict the outcome of these issues or lawsuits.
We believe, however, that TEP is adequately reserved for its transactions with
the CPX and the CISO.
NOTE 8. UNISOURCE ENERGY EARNINGS PER SHARE (EPS)
- --------------------------------------------------
Basic EPS is computed by dividing net income (loss) by the weighted average
number of common shares outstanding during the period. Except when the effect
would be anti-dilutive, the diluted EPS calculation includes the impact of
shares that could be issued upon exercise of outstanding stock options,
contingently issuable shares under equity-based awards or common shares that
would result from the conversion of convertible notes. The numerator in
22
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
calculating diluted earnings per share is net income (loss) adjusted for the
interest on convertible notes (net of tax) that would not be paid if the notes
were converted to common shares.
The following table shows the effects of potential dilutive common stock on
the weighted average number of shares:
Three Months Ended
March 31,
2005 2004
- --------------------------------------------------------------------------------
- In Thousands -
Denominator:
Weighted-average Shares of Common Stock Outstanding 34,635 34,185
Effect of Dilutive Securities:
Convertible Senior Notes - -
Options and Stock Issuable under Employee Benefit Plans
and the Directors' Plan - 703
- --------------------------------------------------------------------------------
Total Shares 34,635 34,888
================================================================================
Due to UniSource Energy's net loss for the quarter ended March 31, 2005,
the following potential shares of common stock were excluded from the diluted
EPS calculation because the effect would be anti-dilutive:
o 1,377,780 shares: the $150 million aggregate principal amount of
convertible notes issued on March 1, 2005 and convertible into
1,377,780 shares (weighted for the number of days outstanding in the
period) at a conversion price of approximately $37.50 per share.
o 746,937 incremental common shares related to options and contingently
issuable shares.
There were no antidilutive options excluded as of March 31, 2004.
NOTE 9. EMPLOYEE BENEFITS PLANS
- --------------------------------
PENSION BENEFIT PLANS
TEP and UES maintain noncontributory, defined benefit pension plans for
substantially all regular employees and certain affiliate employees. Benefits
are based on years of service and the employee's average compensation. TEP and
UES fund the plans by contributing at least the minimum amount required under
Internal Revenue Service regulations. Additionally, we provide supplemental
retirement benefits to certain employees whose benefits are limited by Internal
Revenue Service benefit or compensation limitations.
OTHER POSTRETIREMENT BENEFIT PLANS
TEP provides limited health care and life insurance benefits for retirees.
All regular employees may become eligible for these benefits if they reach
retirement age while working for TEP or an affiliate. UES provides
postretirement medical benefits for current retirees and a small group of active
employees. The majority of UES employees do not participate in the
postretirement medical plan.
The ACC allows TEP and UES to recover postretirement costs through rates
only as benefit payments are made to or on behalf of retirees. The
postretirement benefits are currently funded entirely on a pay-as-you-go basis.
Under current accounting guidance, TEP and UES cannot record a regulatory asset
for the excess of expense calculated per Statement of Financial Accounting
Standards No. 106, Employers' Accounting for Postretirement Benefits Other Than
Pensions, over actual benefit payments.
23
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
COMPONENTS OF NET PERIODIC BENEFIT COST
The components of net periodic benefit costs are as follows:
OTHER POSTRETIREMENT
PENSION BENEFITS BENEFITS
--------------------------------------------------------
Three Months Ended Three Months Ended
March 31, March 31,
2005 2004 2005 2004
- -------------------------------------------------------------------------------------------------------------
-Millions of Dollars -
COMPONENTS OF NET PERIODIC BENEFIT COST
Service Cost $ 1.7 $ 1.5 $ 0.5 $ 0.5
Interest Cost 2.8 2.4 1.0 0.9
Expected Return on Plan Assets (2.9) (2.7) - -
Prior Service Cost Amortization 0.5 0.5 (0.3) (0.4)
Recognized Actuarial (Gain) Loss 0.7 0.4 0.5 0.5
- -------------------------------------------------------------------------------------------------------------
NET PERIODIC BENEFIT COST $ 2.8 $ 2.1 $ 1.7 $ 1.5
=============================================================================================================
NOTE 10. SHARE-BASED COMPENSATION PLANS
- ----------------------------------------
UniSource Energy has issued equity-based compensation awards under the
Directors' Plan and the Omnibus Plan. After February 4, 2004, no new awards can
be granted under the Omnibus Plan. Effective January 1, 2005, we early adopted
the accounting for our share-based plans. Prior to January 1, 2005, we accounted
for those plans under the recognition and measurement principles of APB 25. See
Note 1.
At March 31, 2004, we had stock options, stock units and restricted stock
grants outstanding as discussed below.
STOCK OPTIONS
There were no stock options granted under the Directors' Plan during the
three-month period ended March 31, 2005. Also, there were no stock options
granted under the Omnibus Plan or the Directors' Plan during the three-month
period ended March 31, 2004. Director stock option awards currently vest over
three years, become exercisable in one-third increments on each anniversary date
of the grant and expire on the tenth anniversary of the grant.
A summary of the stock option activity of the Directors' Plan and Omnibus
Plan is as follows:
Three Months Ended March 31,
2005 2004
- --------------------------------------------------------------------------------------------------------
WEIGHTED Weighted
AVERAGE Average
EXERCISE Exercise
SHARES PRICE Shares Price
- --------------------------------------------------------------------------------------------------------
Options Outstanding,
Beginning of Period 2,076,055 $ 16.19 2,478,551 $ 16.04
Granted - - - -
Exercised (212,279) $ 16.44 (203,791) $ 14.90
Forfeited (483) $ 12.28 (1,134) $ 13.85
----------------- ----------------
Options Outstanding,
End of Period 1,863,293 $ 16.16 2,273,626 $ 16.15
================= ================
Options Exercisable,
End of Period 1,855,402 $ 16.16 2,249,624 $ 16.13
Weighted Average Remaining Contractual Life at March 31, 2005: 5.42 years
- --------------------------------------------------------------------------------------------------------
24
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
Stock options awarded on January 1, 2002 accrue dividend equivalents that
are paid in cash on the earlier of the date of exercise of the underlying option
or the date the option expires. Compensation expense is recognized as dividends
are declared. In the first quarter of 2005 and 2004, we recognized compensation
expense of less than $0.1 million for dividend equivalents on stock option
grants.
RESTRICTED STOCK AND STOCK UNITS
In the first quarter of 2005 and 2004, we granted restricted stock awards
to directors totaling 6,528 shares and 6,480 shares, respectively. The grant
date fair value of the shares was $24.51 per share in 2005 and $24.68 per share
in 2004. Directors may elect to receive stock units in lieu of restricted
shares. The restricted shares or stock units become 100% vested on the third
anniversary of the grant date. Compensation expense equal to the fair market
value on the date of the award is recognized over the vesting period. We
recorded compensation expense of less than $0.1 million in the first quarter of
2005 and 2004 related to these awards.
There were no new stock unit awards granted under the Omnibus Plan in the
first quarter of 2005 or 2004. When awards are granted, compensation expense
equal to the fair market value on the date of the award is recognized over a
three or four year vesting period. All stock unit awards under the Omnibus Plan
had fully vested as of March 6, 2004. We recognized compensation expense related
to earlier awards of less than $0.1 million in the first quarter of 2004.
Fully vested but undistributed stock unit awards accrue dividend equivalent
stock units based on the fair market value of common shares on the date the
dividend is paid. Compensation expense is recognized when dividends are
declared. We recorded compensation expense of less than $0.1 million in the
first quarter of 2005 and 2004 for dividend equivalent stock units.
PERFORMANCE SHARES
In May 2003, the Board of Directors approved a grant of performance shares
to key employees under the Omnibus Plan. The shares were to be awarded at the
end of a three-year performance period based on goal attainment. The grant date
fair value was $17.84 per share. Compensation expense was initially recorded
over the performance period based on the anticipated number and market value of
shares to be awarded. As a result of the shareholder vote to approve the
proposed merger, 53,566 performance shares vested and were distributed in March,
2004. See the 2004 Annual Report on Form 10-K, Note 17 of Notes to Consolidated
Financial Statements - Stock-Based Compensation Plans. Compensation expense of
$2 million was recorded in the first quarter of 2004 for this award.
NOTE 11. INCOME AND OTHER TAXES
- --------------------------------
INCOME TAXES
The differences between the income tax expense (benefit) and the amount
obtained by multiplying pre-tax income (loss) by the U.S. statutory federal
income tax rate of 35% are as follows:
UNISOURCE ENERGY TEP
---------------------------------------------------------
Three Months Ended Three Months Ended
March 31, March 31,
2005 2004 2005 2004
- ------------------------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars -
FEDERAL INCOME TAX EXPENSE (BENEFIT) AT STATUTORY RATE $ (1,858) $ 4,316 $ (2,398) $ 1,004
State Income Tax Expense (Benefit), Net of Federal Deduction (244) 566 (315) 130
Depreciation Differences (Flow Through Basis) 680 789 680 789
Tax Credits (131) (129) (131) (129)
Other 27 367 2 280
- ------------------------------------------------------------------------------------------------------------------------------------
TOTAL FEDERAL AND STATE INCOME TAX EXPENSE (BENEFIT) $ (1,526) $ 5,909 $ (2,162) $ 2,074
====================================================================================================================================
25
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
The total Federal and State Income Tax Expense (Benefit) in the table above
is included in UniSource Energy and TEP's income statements.
OTHER TAXES
TEP and UES act as conduits or collection agents for excise tax (sales tax)
as well as franchise fees and regulatory assessments. They record liabilities
payable to governmental agencies when they bill their customers for these
amounts. Neither the amounts billed nor payable are reflected in the income
statement.
NOTE 12. NEW ACCOUNTING PRONOUNCEMENTS
- ---------------------------------------
The FASB recently issued the following Statements of Financial Accounting
Standards (FAS), FASB Interpretations (FIN), and FASB Staff Positions (FSP):
o FIN 47, Accounting for Conditional Asset Retirement Obligations,
issued March 2005, provides guidance for a legal obligation to perform
an asset retirement activity in which the timing and (or) method of
settlement are conditional on a future event that may or may not be
within the control of the entity. The obligation to perform the asset
retirement activity is unconditional even though uncertainty exists
about the timing and (or) method of settlement. FIN 47 requires a
liability be recognized for the fair value of a conditional asset
retirement obligation if the fair value can be reasonably estimated.
FIN 47 is required to be applied by December 31, 2005. We are
evaluating the impact on our financial position and results of
operations of the adoption of FIN 47.
o FSP FIN 46(R)-5, Implicit Variable Interests under FASB Interpretation
No. 46 (revised December 2003), Consolidation of Variable Interest
Entities, issued March 2005, addresses whether a reporting enterprise
should consider whether it holds an implicit variable interest in a
variable interest entity (VIE) or potential VIE when specific
conditions exist. The guidance in FSP FIN 46(R)-5 was effective April
1, 2005, and did not have a significant impact on our financial
statements.
o FAS 153, Exchanges of Nonmonetary Assets, issued December 2004,
requires nonmonetary exchanges be accounted for at fair value,
recognizing any gains or losses, if their fair value is determinable
within reasonable limits and the transaction has commercial substance.
A nonmonetary exchange has commercial substance if future cash flows
of the entity are expected to change significantly as a result of the
exchange. FAS 153 is effective for nonmonetary asset exchange
transactions occurring in fiscal periods beginning after June 15,
2005. The adoption of FAS 153 is not expected to have a significant
impact on our financial statements.
o FSP FAS 109-1, Application of FASB Statement No. 109, Accounting for
Income Taxes, to the Tax Deduction on Qualified Production Activities
Provided by the American Jobs Creation Act of 2004, issued in December
2004, provides guidance on the application of FAS 109 to the provision
within the American Jobs Creation Act of 2004 that provides a tax
deduction, beginning in 2005, on qualified production activities,
including a company's electric generation activities. Under FSP FAS
109-1, recognition of the tax deduction on qualified production
activities is ordinarily reported in the year it is earned. FSP FAS
109-1 did not have a significant impact on our financial statements in
the first quarter. We are evaluating the impact of FSP FAS 109-1 on
our financial position and results of operations for the remainder of
the year.
o FAS 151, Inventory Costs, issued November 2004, is an amendment of
Accounting Research Bulletin (ARB) No. 43, Chapter 4, Inventory
Pricing. FAS 151 clarifies that abnormal amounts of idle facility
expense, freight, handling costs, and wasted materials (spoilage)
should be recognized as current-period charges. FAS 151 also requires
the allocation of fixed production overheads to inventory based on the
normal capacity of the production facilities. FAS 151 is effective for
inventory costs incurred during fiscal years beginning after June 15,
2005. The adoption of FAS 151 is not expected to have a significant
impact on our financial statements.
In June 2004, the EITF published Issue No. 03-1, The Meaning of
Other-Than-Temporary Impairment and Its Application to Certain Investments (EITF
03-1). EITF 03-1 provides application guidance on impairment of securities
accounted for under FAS 115, Accounting for Certain Investments in Debt and
Equity Securities, and cost method investments and requires certain quantitative
and qualitative disclosures for securities that are impaired at the balance
sheet date but for which an other-than-temporary impairment has not been
recognized. The disclosure requirements are effective for reporting periods
ending after December 31, 2003. The FASB issued FSP EITF Issue 03-1-1, Effective
Date of Paragraphs 10-20 of EITF Issue No. 03-1, The Meaning of
26
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
- --------------------------------------------------------------------------------
Other-Than-Temporary Impairment and Its Application to Certain Investments in
September 2004 delaying the effective date of the application guidance on
impairment of securities until the final issuance of FSP EITF Issue 03-1-a. As
of May 6, 2005, a final FSP EITF Issue 03-1-a has not been issued. The adoption
of EITF 03-1 is not expected to have a significant impact on our financial
statements.
NOTE 13. SUPPLEMENTAL CASH FLOW INFORMATION
- --------------------------------------------
A reconciliation of net income to net cash flows from operating activities
follows:
UNISOURCE ENERGY
--------------------------------
Three Months Ended
March 31,
2005 2004
- -------------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
NET INCOME $ (3,783) $ 6,421
ADJUSTMENTS TO RECONCILE NET INCOME
TO NET CASH FLOWS
Depreciation and Amortization Expense 34,824 35,136
Depreciation Recorded to Fuel and Other O&M Expense 1,570 1,556
Amortization of Transition Recovery Asset 9,487 8,597
Net Unrealized Gain on TEP Forward Electric Sales 817 (509)
Net Unrealized Loss on TEP Forward Electric Purchases (1,151) 327
Net Unrealized Gain on MEG Trading Activities 2,203 (1,584)
Amortization of Deferred Debt-Related Costs included in Interest Expense 1,030 2,394
Provision for Bad Debts 824 943
Deferred Income Taxes 18,942 21,061
(Gains) Losses from Equity Method Entities (563) (6,893)
Other 12,936 2,595
Changes in Assets and Liabilities which Provided (Used)
Cash Exclusive of Changes Shown Separately
Accounts Receivable 34,038 15,343
Materials and Fuel Inventory (5,368) (621)
Accounts Payable (33,660) (11,984)
Interest Accrued (29,329) (30,826)
Income Tax Receivable (6,045) (3,561)
Taxes Accrued (7,958) (3,313)
Other Current Assets 27,676 (17,357)
Other Current Liabilities (16,438) 26,314
- -------------------------------------------------------------------------------------------------------------------------
NET CASH FLOWS - OPERATING ACTIVITIES $ 40,052 $ 44,039
=========================================================================================================================
27
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONCLUDED)
- --------------------------------------------------------------------------------
TEP
--------------------------------
Three Months Ended
March 31,
2005 2004
- -------------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
NET INCOME $ (4,690) $ 794
ADJUSTMENTS TO RECONCILE NET INCOME
TO NET CASH FLOWS
Depreciation and Amortization Expense 30,020 30,413
Depreciation Recorded to Fuel and Other O&M Expense 1,570 1,556
Amortization of Transition Recovery Asset 9,487 8,597
Net Unrealized Gain on TEP Forward Electric Sales 817 (509)
Net Unrealized Loss on TEP Forward Electric Purchases (1,151) 327
Amortization of Deferred Debt-Related Costs included in Interest Expense 917 2,317
Provision for Bad Debts 719 560
Deferred Income Taxes 22,615 21,970
Gains from Equity Method Entities (23) (33)
Interest on Note Receivable from UniSource Energy (1,683) (2,320)
Other 3,241 (218)
Changes in Assets and Liabilities which Provided (Used)
Cash Exclusive of Changes Shown Separately
Accounts Receivable 22,786 10,149
Materials and Fuel Inventory (3,373) 257
Accounts Payable (16,105) (6,611)
Interest Accrued (27,171) (27,943)
Interest Received from UniSource Energy 11,013 -
Income Tax Receivable (6,972) (8,813)
Taxes Accrued (8,520) (1,628)
Other Current Assets 6,660 5,506
Other Current Liabilities (2,886) 1,165
- -------------------------------------------------------------------------------------------------------------------------
NET CASH FLOWS - OPERATING ACTIVITIES $ 37,271 $ 35,536
=========================================================================================================================
NOTE 14. REVIEW BY INDEPENDENT ACCOUNTANTS
- -------------------------------------------
With respect to the unaudited condensed consolidated financial information
of UniSource Energy and TEP for the three-month period ended March 31, 2005 and
2004, PricewaterhouseCoopers LLP reported that they have applied limited
procedures in accordance with professional standards for a review of such
information. However, their separate report dated May 6, 2005 appearing herein
states that they did not audit and they do not express an opinion on that
unaudited condensed consolidated financial information. Accordingly, the degree
of reliance on their report on such information should be restricted in light of
the limited nature of the review procedures applied. PricewaterhouseCoopers LLP
is not subject to the liability provisions of Section 11 of the Securities Act
of 1933 (the Act) for their report on the unaudited condensed consolidated
financial information because that report is not a "report" or a "part" of a
registration statement prepared or certified by PricewaterhouseCoopers LLP
within the meaning of Sections 7 and 11 of the Act.
28
ITEM 2. - MANAGEMENT'S DISCUSSI0N AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
- --------------------------------------------------------------------------------
Management's Discussion and Analysis explains the results of operations,
the general financial condition, and the outlook for UniSource Energy and its
four primary business segments and includes the following:
o outlook and strategies,
o operating results during the first quarter of 2005 compared with the
same period in 2004,
o factors which affect our results and outlook,
o liquidity, capital needs, capital resources, and contractual
obligations,
o dividends, and
o critical accounting estimates.
Management's Discussion and Analysis should be read in conjunction with
UniSource Energy and TEP's 2004 Annual Report on Form 10-K and with the
Condensed Consolidated Financial Statements, beginning on page 2, which present
the results of operations for the three months ended March 31, 2005 and 2004.
Management's Discussion and Analysis explains the differences between periods
for specific line items of the Condensed Consolidated Financial Statements.
References in this report to "we" and "our" are to UniSource Energy and its
subsidiaries, collectively.
UNISOURCE ENERGY CONSOLIDATED
OVERVIEW OF CONSOLIDATED BUSINESS
- ---------------------------------
UniSource Energy is a holding company that has no significant operations of
its own. Operations are conducted by UniSource Energy's subsidiaries, each of
which is a separate legal entity with its own assets and liabilities. UniSource
Energy owns substantially all of the outstanding common stock of TEP, and all of
the outstanding common stock of UniSource Energy Services, Inc. (UES),
Millennium Energy Holdings, Inc. (Millennium), and UniSource Energy Development
Company (UED).
TEP, an electric utility, has provided electric service to the community of
Tucson, Arizona, for over 100 years. UES began operations in August 2003. UES
through its two operating subsidiaries, UNS Gas, Inc. (UNS Gas) and UNS
Electric, Inc. (UNS Electric), provides gas and electric service to 30
communities in northern and southern Arizona. Millennium invests in unregulated
businesses, including Global Solar Energy, Inc. (Global Solar), a developer and
manufacturer of thin-film photovoltaic cells and modules. UED engages in
developing generating resources and other project development activities,
including facilitating the expansion of the Springerville Generating Station,
but has no significant operations. We conduct our business in four primary
business segments - TEP's Electric Utility segment, UNS Gas, UNS Electric and
Global Solar.
UniSource Energy was incorporated in the State of Arizona on March 8, 1995
and obtained regulatory approval to form a holding company in November 1997. On
January 1, 1998, TEP and UniSource Energy exchanged shares of stock resulting in
TEP becoming a subsidiary of UniSource Energy. Following the share exchange, TEP
transferred the stock of its subsidiary Millennium to UniSource Energy. See Note
3 of Notes to Condensed Consolidated Financial Statements - Debt and Credit
Facilities.
OUTLOOK AND STRATEGIES
- ----------------------
OPERATING PLANS AND STRATEGIES
Our financial prospects and outlook for the next few years will be affected
by many competitive, regulatory and economic factors. Our plans and strategies
include the following:
o Continue to integrate UES' businesses with UniSource Energy's other
businesses.
o Oversee the construction of Springerville Unit 3 and continue to
enhance the value of existing assets by working with Salt River
Project to facilitate the development of Springerville Unit 4.
29
o Strengthen the capital structure of TEP by using proceeds from the
UniSource Energy convertible notes, borrowings under the UniSource
Energy term loan and some of our excess cash flows to make capital
contributions to TEP and reduce TEP's debt.
o Enhance the value of TEP's transmission system while continuing to
provide reliable access to generation for TEP and UES' retail
customers and market access for all generating assets.
o Promote economic development in our service territories.
o Efficiently manage our generation, transmission and distribution
resources and look for ways to control our operating expenses while
maintaining and enhancing reliability and profitability.
o Expand TEP's and UNS Electric's portfolio of generating and purchased
power resources to meet growing retail energy demand.
o Increase production and sales of Global Solar's thin-film photovoltaic
cells and seek additional investors, or sell all or part of
Millennium's interest, or a combination of both.
o Manage the exit of our other Millennium investments to maximize their
value to shareholders.
To accomplish our goals, during 2005 we expect TEP to spend approximately
$153 million on capital expenditures, and UNS Gas and UNS Electric to spend
approximately $23 million and $26 million, respectively, on capital
expenditures.
While we believe that our plans and strategies will continue to have a
positive impact on our financial prospects and position, we recognize that we
continue to be highly leveraged, and as a result, our access to the capital
markets may be limited or more expensive than for less leveraged companies.
RESULTS OF OPERATIONS
- ---------------------
UniSource Energy recorded a net loss of $4 million, or 11 cents per average
basic share of Common Stock, in the first three months of 2005, compared with
net income of $6 million, or 19 cents per average basic share of Common Stock,
in the same period of 2004. The following factors contributed to the decline:
o a $12 million decrease in TEP's gross margin (total operating revenues
less fuel and purchased power expense) due to mild winter weather,
resulting in lower retail kWh sales, and higher purchased power costs
related to the planned outage at Springerville Unit 2;
o losses of $2 million at Global Solar, compared with losses of $1
million in the first quarter of 2004; and
o a net loss of $1 million at MEH's other investments, compared with net
income of $3 million in the first quarter of 2004, due primarily to
the sale of an investment; partially offset by
o a $3 million decrease in total interest expense due to lower balances
on long-term debt and capital lease obligations, and lower fees on the
Credit Agreement entered into by TEP in March 2004, compared to the
first quarter of 2004; and
o a $2 million decrease in Other Operations and Maintenance (O&M)
expense. In the first quarter of 2004, O&M included $1 million of
expenses related to the proposed acquisition of UniSource Energy by
Saguaro Utility (Saguaro), while in the first quarter of 2005, TEP
reduced O&M expense due to a $1 million pre-tax gain on the sale of
emissions allowances.
CONTRIBUTION BY BUSINESS SEGMENT
The table below shows the contributions to our consolidated after-tax
earnings by our four business segments.
30
THREE MONTHS ENDED MARCH 31, 2005 2004
-Millions of Dollars-
------------------------------------- --------------------------------------
BUSINESS SEGMENT
TEP $ (5) $ 1
UNS Gas 4 4
UNS Electric 1 1
Global Solar (2) (1)
Other (1) (2) 1
------------------------------------- ------------------ -------------------
Consolidated Net Income $ (4) $ 6
===================================== ================== ===================
(1) Includes: for 2005, interest expense (net of tax) on the
convertible note offering by UniSource Energy; interest expense (net of
tax) on the note payable from UniSource Energy to TEP; costs associated
with the proposed acquisition of UniSource Energy by Saguaro as
previously discussed; UniSource Energy parent company expenses; income
and losses from other Millennium investments; and income and losses from
UED.
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
UNISOURCE ENERGY CONSOLIDATED CASH FLOWS
THREE MONTHS ENDED MARCH 31, 2005 2004
-Millions of Dollars-
------------------------------------ ---------------- -----------------
Cash provided by (used in):
Operating Activities $ 40 $ 44
Investing Activities (31) (28)
Financing Activities 41 (56)
------------------------------------ ---------------- -----------------
Net Increase (Decrease) in Cash $ 50 $ (40)
==================================== ================ =================
UniSource Energy's consolidated cash flows are provided primarily from
retail and wholesale energy sales at TEP and UES, net of the related payments
for fuel and purchased power. Cash from operations is lowest in the first
quarter and highest in the third quarter due to TEP's summer peaking load.
We use our available cash primarily to:
o finance capital expenditures at TEP, UNS Gas and UNS Electric;
o pay dividends to shareholders; and
o reduce leverage at TEP by repaying or repurchasing debt and investing
in lease debt.
The primary source of liquidity for UniSource Energy, the parent company,
is dividends it receives from its subsidiaries, primarily TEP. Under our tax
sharing agreement, our subsidiaries make income tax payments to UniSource
Energy, which makes payments on behalf of the consolidated group.
As part of our ACC Holding Company Order, we must invest at least 30% of
any proceeds of UniSource Energy equity issuances in TEP until TEP's equity
reaches 37.5% of total capital (excluding capital leases).
As of May 4, 2005, cash and cash equivalents available to UniSource Energy
was approximately $94 million. This balance includes proceeds from UniSource
Energy's Convertible Senior Notes issued March 1, 2005. See Convertible Senior
Notes, below.
OPERATING ACTIVITIES
In the first three months of 2005, net cash flows from operating activities
decreased by $4 million compared with the same period in 2004. The following
factors contributed to the increase:
o an $8 million decline in cash receipts from electric and gas sales,
net of fuel and purchased power costs paid, due to the planned outage
at Springerville Unit 2 and mild winter weather in TEP's service
territory; partially offset by
31
o a $4 million decrease in total taxes paid, net of income tax refunds
received, due to a smaller final tax payment related to prior year
consolidated income tax returns.
INVESTING ACTIVITIES
Net cash used for investing activities was $3 million higher in the first
three months of 2005 compared with the same period in 2004, primarily due to the
following factors:
o capital expenditures were $14 million higher in the first three months
of 2005 due primarily to a planned maintenance outage at Springerville
and TEP's share of the construction costs of the Luna Energy Facility;
partially offset by
o other cash receipts of $6 million in the first three months of 2005
due primarily to the redemption of a $5 million certificate of deposit
at TEP; and
o $4 million used in the first three months of 2004 to purchase
Springerville lease debt at TEP.
FINANCING ACTIVITIES
Net cash flows from financing activities was $41 million in the first three
months of 2005 compared with net cash used for financing activities of $56
million in the first three months of 2004. The following factors contributed to
the change:
o UniSource Energy issued $150 million of Convertible Senior Notes in
March 2005;
o TEP redeemed $53 million of First Mortgage Bonds in March 2005; and
o TEP's payments on capital lease obligations were $5 million higher in
the first three months of 2005.
As a result of the activities described above, our consolidated cash and
cash equivalents increased to $204 million at March 31, 2005, from $154 million
at December 31, 2004. We invest cash balances in high-grade money market
securities with an emphasis on preserving the principal amounts invested.
At May 4, 2005, our consolidated cash balance, including cash equivalents,
was approximately $94 million. This balance includes proceeds from UniSource
Energy's Convertible Senior Notes issued March 1, 2005. See Convertible Senior
Notes, below.
In the event that we experience lower cash from operations in 2005, we will
adjust our discretionary uses of cash accordingly. We believe, however, that we
will continue to have sufficient cash flow to cover our capital needs, as well
as required debt payments and dividends to shareholders.
Convertible Senior Notes
------------------------
On March 1, 2005, UniSource Energy issued $150 million aggregate principal
amount of 4.50% Convertible Senior Notes (Convertible Senior Notes) due 2035 in
a private placement. The Convertible Senior Notes are unsecured. Each $1,000
principal amount of Convertible Senior Notes is convertible into 26.6667 shares
of UniSource Energy Common Stock at any time, representing a conversion price of
approximately $37.50 per share of our Common Stock, subject to adjustment in
certain circumstances.
The Convertible Senior Notes bear interest at an annual rate of 4.50%
payable semi-annually in arrears on each March 1 and September 1, commencing on
September 1, 2005. In addition, beginning on March 1, 2015, the Convertible
Senior Notes will also, in certain circumstances, bear contingent interest at
the annual rate of 0.35%.
Beginning on March 5, 2010, we will have the option to redeem the
Convertible Senior Notes, in whole or in part, for cash, at a price equal to
100% of the principal amount plus accrued interest. If certain change of control
transactions occur, or our common stock is no longer listed on a national
securities exchange, holders of the Convertible Senior Notes may require
32
UniSource Energy to repurchase the Convertible Senior Notes, in whole or in
part, for cash. If one of these events occurs prior to March 5, 2010, we may be
required to pay a make-whole premium payable in shares of common stock.
Additionally, the holders of the Convertible Senior Notes may require us to
repurchase for cash, all or part, of the Convertible Senior Notes on March 1,
2015, 2020, 2025 and 2030. The repurchase price will be 100% of the principal
amount of the Convertible Senior Notes plus accrued interest.
The Convertible Senior Notes may become immediately payable if an event of
default occurs. An event of default includes failure to make required payments
on the Convertible Senior Notes, acceleration of $50 million or more of
indebtedness for borrowed money at UniSource Energy or TEP or certain bankruptcy
events at UniSource Energy or TEP. Neither TEP nor any other subsidiary of
UniSource Energy has guaranteed UniSource Energy's obligations on the
Convertible Senior Notes.
UniSource Credit Agreement
--------------------------
On April 15, 2005, UniSource Energy entered into a $105 million five-year
credit agreement with a group of lenders (UniSource Credit Agreement) which
expires on April 15, 2010. The UniSource Credit Agreement includes a $90 million
term loan facility and a $15 million revolving credit facility. In addition,
UniSource Energy is required to make quarterly payments of $1.25 million
beginning June 2005 with the balance due at maturity.
Interest is payable on borrowings under the UniSource Credit Agreement at a
Eurodollar rate or Alternate Base Rate rate. Eurodollar loans would bear
interest at adjusted LIBOR plus 1.75%. Alternate Base Rate loans would bear
interest in an amount equal to the sum of (1) the greater of the federal funds
rate plus 1/2 of 1% or the agent bank's reference rate, and (2) 0.75%. In the
event that, after June 30, 2005, TEP, because of regulatory restrictions, does
not have the ability to pay 100% of its current year net income as dividends,
interest rates would increase by 0.25%.
The UniSource Credit Agreement contains a number of covenants restricting
additional indebtedness, liens, mergers, sales of assets and investments and
acquisitions. Additionally, the UniSource Credit Agreement contains several
financial covenants including: (1) a minimum cash flow to interest coverage
ratio determined on a UniSource Energy standalone basis and (2) a maximum
leverage ratio determined on a consolidated basis. The UniSource Credit
Agreement allows UniSource Energy to pay dividends, if after giving effect to
the dividend payment, UniSource Energy and it subsidiaries have more than $15
million of unrestricted cash and unused revolving credit.
The UniSource Credit Agreement may become immediately payable if an event
of default occurs. An event of default includes failure to make required
payments under the UniSource Credit Agreement, failure of UniSource Energy or
certain subsidiaries to make payments or default on debt greater than $20
million, or certain bankruptcy events at UniSource Energy or certain
subsidiaries. The UniSource Credit Agreement is collateralized by a pledge of
the capital stock of Millennium, UES and UED.
UniSource Energy expects that borrowings will be made from time to time
under the revolving credit facility component of the UniSource Credit Agreement
to meet temporary cash needs.
Use of Proceeds
---------------
On March 1, 2005, UniSource Energy used $106 million of the net proceeds
from the sale of the Convertible Senior Notes to repay its $95 million
promissory note to TEP plus accrued interest of $11 million.
UniSource Energy expects to borrow the entire $90 million available under
the term loan facility by June 30, 2005 and use the proceeds to make a capital
contribution to TEP. It is anticipated that this $90 million capital
contribution, together with the proceeds TEP received from the $95 million
inter-company note repayment in March 2005 (described above) and any additional
capital contributions to TEP from the proceeds of UniSource Energy's issuance of
the Convertible Senior Notes in March 2005, will be used by TEP to repurchase or
redeem $225 million of fixed-rate tax-exempt debt obligations.
As stated in a recently expired tender offer, TEP has agreed to purchase
$147 million of its 1997 Pima Series B and $74 million of its 1997 Pima Series C
fixed-rate tax-exempt debt obligations (Repurchased Bonds) from bondholders on
May 11, 2005, at a price of $101.50 per $100 principal amount. Additionally, TEP
will redeem at par $4 million of bonds not tendered on May 18, 2005. TEP does
not plan on canceling the Repurchased Bonds. The Repurchased Bonds will remain
outstanding under their respective indentures; however, the Repurchased Bonds
will not be presented in our financial statements. TEP may choose to cancel or
33
resell the Repurchased Bonds to third parties in the future. Upon completion of
these purchases and redemptions in the principal amount of $225 million, TEP
expects its ratio of equity to total capitalization (excluding capital leases)
will improve to 40%, thereby allowing TEP to dividend up to 100% of its current
year net income to UniSource Energy. See, Tucson Electric Power, Bond
Repurchases and Redemptions, and Tucson Electric Power Company, Liquidity and
Capital Resources, Dividends on Common Stock, below.
On March 10, 2005, UniSource Energy used $10 million of the net proceeds
from the sale of the Convertible Senior Notes to make an equity contribution of
$6 million to UNS Gas and an equity contribution of $4 million to UNS Electric.
GUARANTEES AND INDEMNITIES
In the normal course of business, UniSource Energy and certain subsidiaries
enter into various agreements providing financial or performance assurance to
third parties on behalf of certain subsidiaries. We enter into these agreements
primarily to support or enhance the creditworthiness of a subsidiary on a
stand-alone basis. The most significant of these guarantees are UES' guarantee
of $160 million of aggregate principal amount of senior unsecured notes issued
by UNS Gas and UNS Electric to purchase the Citizens Communication Company
(Citizens') Arizona gas and electric system assets, UES' guarantee of a $40
million revolving credit facility available to UNS Gas and UNS Electric,
UniSource Energy's guarantee of approximately $8 million in natural gas and
supply payments and building lease payments for UNS Gas and UNS Electric, and
subsidiaries of Millennium, and Millennium's guarantee of approximately $2
million in commodity-related payments for MEG at March 31, 2005. To the extent
liabilities exist under the contracts subject to these guarantees, such
liabilities are included in the consolidated balance sheets.
In addition, UniSource Energy and its subsidiaries have indemnified the
purchasers of interests in certain investments from additional taxes due for
years prior to the sale. The terms of the indemnifications provide for no
limitation on potential future payments; however, we believe that we have abided
by all tax laws and paid all tax obligations. We have not made any payments
under the terms of these indemnifications to date.
We believe that the likelihood that UniSource Energy or TEP would be
required to perform or otherwise incur any significant losses associated with
any of these guarantees is remote.
CONTRACTUAL OBLIGATIONS
There are no significant changes in our contractual obligations or other
commercial commitments from those reported in our 2004 Annual Report on Form
10-K, other than the UniSource Energy Credit Agreement (described above) and the
UNS Gas/UNS Electric Credit Agreement, described below.
DIVIDENDS ON COMMON STOCK
The following table shows the declared dividends to UniSource Energy
shareholders for 2005.
DIVIDEND AMOUNT
DECLARATION DATE RECORD DATE PAYABLE DATE PER SHARE OF COMMON STOCK
- ---------------- ------------------- ------------- --------------------------
February 4, 2005 February 15, 2005 March 8, 2005 $0.19
May 6, 2005 May 18, 2005 June 10, 2005 $0.19
- ---------------- ------------------- ------------- --------------------------
INCOME TAX POSITION
At March 31, 2005, UniSource Energy and TEP had, for federal and state
income tax filing purposes, the following carryforward amounts:
UNISOURCE ENERGY TEP
Amount Expiring Amount Expiring
- ------------------------------ ---------------------- ------------- ----------------------- -------------
-Millions of Dollars- Year -Millions of Dollars- Year
NET OPERATING LOSSES $ 18 2021-2022 $ - -
INVESTMENT TAX CREDIT 5 2004-2024 5 2004-2024
AMT CREDIT 100 - 92 -
- ------------------------------ ---------------------- ------------- ----------------------- -------------
34
The $18 million in NOL carryforwards is subject to limitation due to a
reorganization of certain Millennium entities in December 2002. The future use
of these losses is dependant upon the generation of sufficient future taxable
income at the separate company level. See Critical Accounting Estimates,
Deferred Tax Valuation - TEP and Millennium, below.
TUCSON ELECTRIC POWER COMPANY
RESULTS OF OPERATIONS
- ---------------------
The financial condition and results of operations of TEP are currently the
principal factors affecting the financial condition and results of operations of
UniSource Energy on an annual basis. The following discussion relates to TEP's
utility operations, unless otherwise noted.
SALES OPERATING REVENUE
THREE MONTHS ENDED MARCH 31, 2005 2004 2005 2004
-Millions of kWh- -Millions of Dollars-
- --------------------------------------------- -------------- ------------- ------------ --------------
ELECTRIC RETAIL SALES:
Residential 649 719 $ 55 $ 58
Commercial 351 358 36 37
Industrial 512 490 36 36
Mining 220 192 10 9
Public Authorities 44 50 3 3
- --------------------------------------------- -------------- ------------- ------------ --------------
TOTAL ELECTRIC RETAIL SALES 1,776 1,809 140 143
- --------------------------------------------- -------------- ------------- ------------ --------------
ELECTRIC WHOLESALE SALES DELIVERED:
Long-term Contracts 308 346 14 15
Other Sales 454 543 24 25
Transmission - - 2 2
Net Unrealized Gain (Loss) on Forward
Sales of Energy - - (1) -
- --------------------------------------------- -------------- ------------- ------------ --------------
TOTAL ELECTRIC WHOLESALE SALES 762 889 39 42
- --------------------------------------------- -------------- ------------- ------------ --------------
TOTAL ELECTRIC SALES 2,538 2,698 $ 179 $ 185
============================================= ============== ============= ============ ==============
WEATHER DATA:
Heating Degree Days 775 877
10-Year Average 796 796
% Over / (Under) Prior Year (12%) 28%
% Over / (Under) 10-Year Average (3%) 10%
- --------------------------------------------- -------------- ------------- ------------ --------------
Total revenues from kWh sales to retail customers decreased by $3 million,
or 2%, in the first quarter of 2005 compared with the first quarter of 2004,
resulting from lower energy demand from residential customers. Heating degree
days were 12% lower than last year and 3% lower than the 10-year average. Higher
mining and industrial kWh sales partially offset the lower residential demand.
The average price of copper was 10% higher in first quarter of 2005 compared
with the same period last year, leading to increased mining activity and a 15%
increase in kWh sales to TEP's mining customers; revenues from TEP's mining
customers increased $1 million. Total retail kWh sales decreased by 2% in the
first quarter of 2005 compared with the same period last year.
Wholesale revenues decreased $3 million, or 7%, in the first quarter of
2005 compared with the first quarter of 2004. Wholesale sales opportunities were
limited in the first quarter of 2005 due to a planned outage at TEP's
Springerville Unit 2. The average wholesale market price of energy was $45 per
MWh in 2005, compared with $40 per MWh in 2004. See Factors Affecting Results of
Operations, Western Energy Markets, Market Prices, below.
OPERATING EXPENSES
FUEL AND PURCHASED POWER EXPENSE
TEP's fuel and purchased power expense, and energy resources for the first
quarters of 2005 and 2004 are shown in the table below.
35
GENERATION EXPENSE
THREE MONTHS ENDED MARCH 31, 2005 2004 2005 2004
-Millions of kWh- -Millions of Dollars-
- -------------------------------------------- ----------------------- -------------------------
Coal-Fired Generation 2,405 2,763 $ 42 $ 47
Gas-Fired Generation 56 12 5 -
- -------------------------------------------- --------- ------------- ------------ -------------
Total Generation 2,461 2,775 47 47
Purchased Power 268 95 13 6
- -------------------------------------------- --------- ------------- ------------ -------------
Total Resources 2,729 2,870 $ 60 $ 53
============ =============
Less Line Losses, Company Use and Other 191 172
- -------------------------------------------- --------- -------------
Total Energy Sold 2,538 2,698
- -------------------------------------------- --------- -------------
A planned outage at TEP's 380-megawatt coal-fired Springerville Unit 2
facility led to higher gas-related fuel costs and higher purchased power
expenses during the first three months of 2005. Total fuel expense at TEP's
generating plants was $47 million in the first three months of both 2005 and
2004. Coal-related fuel expense was $5 million lower than last year due to the
planned outage of Springerville Unit 2. Gas-related fuel expense increased $5
million due to the higher use of TEP's gas-fired generating resources as well as
higher commodity prices for gas. The average price per MMBtu of gas at the
Permian basin was up 11% compared with the first quarter of 2004.
Purchased power expense increased $7 million compared with the first
quarter of 2004, due to replacement power purchases and higher wholesale energy
prices. Average wholesale energy prices on the Dow Jones Palo Verde Index were
up 13% compared with last year. See Factors Affecting Results of Operations,
Western Energy Markets, Market Prices, below.
The table below shows the average cost per kWh for TEP's generating plants
by fuel type.
2005 2004
-cents per kWh-
- ------------------------------ ------------------- ------------------
Coal 1.75 1.70
Gas 8.93 8.33
All fuels 1.91 1.71
- ------------------------------ ------------------- ------------------
OTHER OPERATING EXPENSES
Other O&M expense was unchanged in the first quarter of 2005 compared with
the same period in 2004.
Amortization of the Transition Recovery Asset (TRA) increased $1 million in
the first quarter of 2005. Amortization of the TRA is the result of the 1999
Settlement Agreement (TEP Settlement Agreement) with the ACC, which changed the
accounting method for TEP's generation operations. This item reflects the
recovery, through 2008, of transition recovery assets which were previously
regulatory assets of the generation business. The amount of amortization is a
function of the TRA balance and total kWh consumption by TEP's distribution
customers.
The table below shows estimated TRA amortization and unamortized TRA
balances for the remainder of 2005 through 2008.
FUTURE ESTIMATED UNAMORTIZED
TRA AMORTIZATION TRA BALANCE
-Millions of Dollars-
----------------------- ---------------------------- -------------------
2005 $ 55 $ 169
2006 64 105
2007 73 32
2008 32 -
----------------------- ---------------------------- -------------------
OTHER INCOME (DEDUCTIONS)
36
TEP's Income statement includes inter-company Interest Income of $2 million
in the first quarter of 2005, and $2 million in the first quarter of 2004. This
represented Interest Income on a promissory note TEP received from UniSource
Energy in exchange for the transfer to UniSource Energy of its stock in
Millennium in 1998. On UniSource Energy's Consolidated Statement of Income, this
Interest Income, as well as UniSource Energy's related interest expense, was
eliminated as an inter-company transaction. In March 2005, UniSource Energy
repaid the inter-company promissory note. See Liquidity and Capital Resources,
TEP Cash Flows, Inter-Company Note from UniSource Energy, below.
INTEREST EXPENSE
Total Interest Expense decreased by $3 million, or 9%, in the first quarter
of 2005 due to: lower Letter of Credit fees on the Credit Agreement entered into
by TEP in March 2004; lower interest expense resulting from the July 2004
redemption of $27 million of 8.5% First Mortgage Bonds; and fees written off in
March 2004 when TEP refinanced its Credit Agreement.
INCOME TAX EXPENSE
TEP recorded Income Tax Benefits of $2 million in the first quarter of 2005
due to a $7 million Loss Before Income Taxes. In the first quarter of 2004, TEP
recorded Income Tax Expense of $2 million.
FACTORS AFFECTING RESULTS OF OPERATIONS
- ---------------------------------------
COMPETITION
The electric utility industry has undergone significant regulatory change
in the last few years designed to encourage competition in the sale of
electricity and related services. However, the recent experience in California
with deregulation has caused many states, including Arizona, to re-examine the
viability of retail electric deregulation.
As of January 1, 2001, all of TEP's retail customers are eligible to choose
an alternate energy supplier. Currently none of TEP's retail customers are
receiving service from other providers. TEP has met all conditions required by
the ACC to facilitate electric retail competition, including ACC approval of
TEP's direct access tariffs. ESPs must meet certain conditions before
electricity can be sold competitively in TEP's service territory. Examples of
these conditions include ACC certification of ESPs, and execution of and
compliance with direct access service agreements with TEP.
In January 2005, an Arizona Court of Appeals decision became final in which
the Court held invalid certain portions of the ACC rules on retail competition
and related market pricing. Based on this decision, we expect that the ACC will
address the competition rules in an administrative proceeding during 2005. We
cannot predict what changes, if any, the ACC will make to the competition rules.
See Rates, Recent Motion Filed with ACC, below.
TEP competes against gas service suppliers and others that provide energy
services. Other forms of energy technologies may provide competition to TEP's
services in the future, but to date, are not financially viable alternatives for
its retail customers. Self-generation by TEP's large industrial customers could
also provide competition for TEP's services in the future, but has not had a
significant impact to date.
In the wholesale market, TEP competes with other utilities, power marketers
and independent power producers in the sale of electric capacity and energy.
RATES
TEP'S SETTLEMENT AGREEMENT AND RETAIL ELECTRIC COMPETITION RULES
In September 1999, the ACC approved the Retail Electric Competition Rules
(Rules) that provided a framework for the introduction of retail electric
competition in Arizona. In November 1999, the ACC approved the Settlement
Agreement between TEP and certain customer groups related to the implementation
of retail electric competition in Arizona.
The Rules and the Settlement Agreement established:
o a period, November 1999 through 2008, for TEP to transition its
generation assets from a cost of service based rate structure to a
market, or competitive, rate structure;
37
o the recovery through rates during the transition period of $450
million of stranded generation costs through a fixed competitive
transition charge (fixed CTC);
o capped rates for TEP retail customers through 2008;
o an ACC interim review of TEP retail rates in 2004;
o unbundling of electric services with separate rates or prices for
generation, transmission, distribution, metering, meter reading,
billing and collection, and ancillary services;
o a process for Energy Service Providers (ESPs) to become licensed by
the ACC to sell generation services at market prices to TEP retail
customers;
o access, as noted above, for TEP retail customers to buy market priced
generation services from ESPs beginning in 2000 (currently, no TEP
customers are purchasing generation services from ESPs);
o transmission and distribution services would remain subject to
regulation on a cost of service basis; and
o beginning in 2009, TEP's generation would be market based and its
retail customers would pay the market rate for generation services.
2004 General Rate Case Information
----------------------------------
On June 1, 2004, as required by the Settlement Agreement, TEP filed general
rate case information with the ACC. TEP's filing does not propose any change in
retail rates, and under the terms of the Settlement Agreement, no rate case
filed by TEP through 2008 may result in a net rate increase. However, absent the
restriction on raising rates, TEP believes that the data in its filing would
justify an increase in retail rates of 16%.
The general rate case information uses a historical test year ended
December 31, 2003 and establishes, based on TEP's standard offer service, that
TEP is experiencing a revenue deficiency of $111 million. The rate case
information includes, among other things, Springerville Unit 1 costs and other
generation costs including fuel costs in excess of those recovered through
existing rates. The proposed weighted cost of capital for the test year ended
December 31, 2003 is 8.78%, including an 11.5% return on equity (increased from
10.67% currently authorized). The rate case information uses a hypothetical 40%
equity capitalization (excluding capital lease obligations) rather than the
hypothetical 37.5% equity capitalization used in TEP's last general rate case.
TEP's actual equity capitalization (excluding capital lease obligations) at
March 31, 2005 was 29.6%. As discussed above, in the first half of 2005, TEP
expects to increase common equity to 40% of capitalization (excluding capital
lease obligations). See TEP, Dividends on Common Stock, below for further
information regarding improvements to TEP's capital structure. Despite the
indicated revenue deficiency, the ACC could conclude that TEP should decrease
rates after June 1, 2005; any such determination would be strongly opposed by
TEP.
A procedural order was issued in February 2005 that outlined how the review
of TEP's general rate case information will proceed. The schedule calls for
staff and intervenor testimony to be filed by June 13, 2005 and hearings, as
appropriate, before the administrative law judge to begin September 12, 2005.
Transition
----------
The Settlement Agreement provides that TEP's fixed CTC will expire when
TEP's $450 million transition asset is fully amortized and recovered or on
December 31, 2008, whichever is earlier. Based on current projections of retail
sales, the transition recovery asset is expected to be fully amortized by
mid-2008. The Settlement Agreement also specifies that TEP's floating
competitive transition charge (floating CTC) will expire on December 31, 2008.
This charge, which moves inversely to changes in market-based generation
services rates, presently appears as a credit on retail customer bills. Based on
current forward pricing in the wholesale energy markets, TEP anticipates that
the floating CTC will continue to appear as a credit on retail customer bills
through 2008. After the expiration of the floating CTC, TEP's rates for
generation services should be market based. TEP anticipates that it will submit
a rate filing to address the rates that will go into effect after the expiration
of the 1999 Settlement Agreement.
Absent any other change to TEP's retail rate structure, including continued
inability to recover actual costs, TEP estimates that the expiration of the
fixed CTC in 2008 (which has provided revenues, on average of .93 cents per kWh
sold) would result in an average decrease in revenues from retail rates of
approximately 12% relative to revenues from current retail rates. However,
absent any other change except the expiration of the fixed CTC, the expiration
in 2008 of the floating CTC would result in market-based generation services
rates which would, based on current pricing in the wholesale energy markets,
produce a retail rate increase in January 2009 of approximately 10-15% relative
to current retail rates.
38
We are operating pursuant to the TEP Settlement Agreement. However, we
cannot predict the future rate methodologies for TEP which the ACC could
authorize, including whether the ACC will permit or require market-based rates
for generation services, reinstate cost of service ratemaking for all or a
portion of TEP's generation services or require an alternate methodology to
determine rates for TEP's generation services. Under any circumstances, TEP will
seek appropriate recovery and return on its investment in assets used to serve
its customers.
In the event that the ACC reinstates cost of service ratemaking for TEP's
generation services and does not allow other factors that have changed in the
intervening years to be considered, significant retail rate decreases could
occur. TEP expects that, in establishing future rates, TEP and the ACC will
review the entirety of the retail rate structure rather than focusing solely on
any one of the elements noted above. Although TEP is unable to predict the type
and level of future retail rates, TEP believes that the 2004 general rate case
information filed with the ACC evidences that there have been a number of
factors that have changed since the Settlement Agreement was approved that
justify increasing or maintaining retail rates at current levels.
Recent Motion Filed with ACC
----------------------------
Given the recent court action described above, the ACC may revise its Rules
and rate methodologies prior to the expiration in 2008 of the TEP Settlement
Agreement. A new structure could replace that established pursuant to the TEP
Settlement Agreement prior to January 2009.
In an effort to resolve the uncertainty surrounding the continued
applicability of the Rules and the methodology that will be applied to determine
TEP's rates for generation service after the CTCs expire, TEP filed a motion
with the ACC on May 4, 2005 requesting that the ACC issue an order declaring its
position regarding the status of the Rules and the rate treatment that will be
afforded to TEP's generation assets after 2008.
The motion states TEP's preference for the ACC to adhere to the 1999
Settlement Agreement and continue to authorize TEP to charge market-based rates
for generation services after December 31, 2008. The motion also states that, if
the ACC intends to rescind TEP's authorization to charge market-based rates for
its generation services, that change will have immediate consequences for the
Settlement Agreement, the 2004 general rate case information filing and future
TEP rate cases. Accordingly, TEP requested that the ACC clarify its intentions
in this regard. In addition, TEP requested that a procedural conference be held
in the 2004 rate review proceedings to discuss the status of that case pending
the issuance of an order in response to TEP's motion. TEP cannot predict when,
or how, the ACC will respond to the motion.
WESTERN ENERGY MARKETS
As a participant in the western U.S. wholesale power markets, TEP is
directly and indirectly affected by changes in market conditions and market
participants. TEP competes with other utilities, power marketers and independent
power producers in the sale of electric capacity and energy at market-based
rates in the wholesale market.
As of March 31, 2005, electric generating capacity in Arizona has grown to
approximately 25,000 MW; an increase of nearly 60% since 2001. A majority of the
growth over the last three years is the result of 16 new or upgraded gas-fired
generating units with a combined capacity of approximately 9,200 MW. In
addition, the presence of fewer creditworthy counterparties, as well as legal,
political and regulatory uncertainties, has reduced market liquidity and trading
volume.
MARKET PRICES
The average market price for around-the-clock energy based on the Dow Jones
Palo Verde Index increased in the first quarter 2005, as did the average price
for natural gas based on the Permian Index. Average market prices for
around-the-clock energy began to rise in February 2003 and stayed at elevated
levels during 2004 and the first three months of 2005 due to high natural gas
prices from increased demand and production and storage level concerns. As a
result of all of these factors, TEP's natural gas and purchased power expenses
were higher in the first three months of 2005 than the same period in 2004.
Prices have continued in this range to date; however, we cannot predict whether
these higher prices will continue, or whether changes in various factors that
influence demand and supply will cause prices to fall during 2005.
39
AVERAGE MARKET PRICE FOR AROUND-THE-CLOCK ENERGY $/MWH
--------------------------------------------------------- ----------------
Quarter ended March 31, 2005 $ 45
Quarter ended March 31, 2004 40
--------------------------------------------------------- ----------------
AVERAGE MARKET PRICE FOR NATURAL GAS $/MMBTU
--------------------------------------------------------- ----------------
Quarter ended March 31, 2005 $ 5.55
Quarter ended March 31, 2004 5.02
TEP typically uses generation from its facilities fueled by natural gas and
purchased power, in addition to energy from its coal-fired facilities, to meet
the summer peak demands of its retail customers and to meet local reliability
needs. Some of these purchased power contracts are price indexed to natural gas
prices. Short-term and spot power purchase prices are also closely correlated to
natural gas prices. Due to its increasing seasonal gas and purchased power
usage, TEP hedges a portion of its total natural gas exposure from plant fuel
and gas-indexed purchased power with fixed price contracts for a maximum of
three years. TEP currently has approximately 50% of this exposure hedged for the
May through October summer peak period of 2005 at a weighted average price of
$5.50 per MMBtu. TEP purchases its remaining gas fuel needs and purchased power
in the spot and short-term markets.
We expect the market price and demand for capacity and energy to continue
to be influenced by factors including:
o weather;
o continued population growth in the western U.S.;
o economic conditions in the western U.S.;
o availability of generating capacity throughout the western U.S.;
o the extent of electric utility industry restructuring in Arizona,
California and other western states;
o the effect of FERC regulation of wholesale energy markets;
o the availability and price of natural gas;
o availability of hydropower;
o transmission constraints; and
o environmental regulations and the cost of compliance.
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
TEP CASH FLOWS
TEP's capital requirements consist primarily of capital expenditures and
optional and mandatory redemptions of long-term debt and capital lease
obligations. Cash flow from operations typically is the lowest in the first
quarter and highest in the third quarter due to TEP's summer peaking load.
THREE MONTHS ENDED MARCH 31, 2005 2004
-Millions of Dollars-
----------------------------------------------------------- --------------- --------------
Net Cash Flows - Operating Activities $ 37 $ 36
Capital Expenditures (34) (23)
----------------------------------------------------------- --------------- --------------
Net Cash Flows after Capital Expenditures* 3 13
----------------------------------------------------------- --------------- --------------
Debt Maturities (1) (1)
Retirement of Capital Lease Obligations (48) (44)
Proceeds from Investment in Springerville
Lease Debt and Equity 8 8
----------------------------------------------------------- --------------- -------------
Net Cash Flows Available after Required Payments* $ (38) $ (24)
=========================================================== =============== ==============
* We believe that Net Cash Flows after Capital Expenditures and Net Cash
Flows Available After Required Payments, which are non-GAAP financial
measures, provide useful information to investors as measures of liquidity
and our ability to meet our capital requirements and mandatory redemptions
of debt and capital lease obligations.
During 2005, TEP expects to generate sufficient internal cash flows to fund
its operating activities, construction expenditures, required debt maturities,
and to pay dividends to UniSource Energy. However, TEP's cash flows may vary due
to changes in wholesale revenues, changes in short-term interest rates, and
40
other factors. TEP currently has $60 million available under its Revolving
Credit Facility which it may borrow if cash flows fall short of expectations or
if monthly cash requirements temporarily exceed available cash balances. TEP may
temporarily borrow funds under its Revolving Credit Facility in May 2005 in
connection with the redemption of $225 million of fixed-rate tax-exempt debt.
See UniSource Energy, Liquidity and Capital Resources, UniSource Energy Credit
Agreement, Use of Proceeds, above, and Bond Issuances and Redemptions, below.
OPERATING ACTIVITIES
In the first three months of 2005, net cash flows from operating activities
increased by $1 million compared with the same period in 2004. The following
factors contributed to the increase:
o an $11 million increase in interest received, due primarily to
interest received from UniSource Energy when it repaid its $95 million
inter-company loan to TEP;
o a $5 million decrease in Income Taxes Paid due the timing of payments
in the first three months of 2005 compared with the same period last
year;
o a $3 million decrease in total interest paid due to lower capital
lease obligation balances, lower fees under TEP's Credit Agreement
that was entered into in March 2004 and lower long-term debt balances;
partially offset by
o a $6 million decrease in total cash receipts from retail and electric
wholesale sales, net of fuel and purchased power costs, due to the
planned outage at Springerville Unit 2 and mild winter weather;
o a $5 million increase in wages paid due to higher incentive
compensation compared to last year; and
o a $5 million increase in O&M expense related to the planned outage at
Springerville Unit 2 and maintenance costs at the San Juan Generating
Station.
FINANCING ACTIVITIES
Net cash used for financing activities was $40 million lower in the first
three months of 2005 compared with the same period in 2004. The following
factors contributed to the decrease:
o TEP received $95 million from UniSource Energy as a repayment for an
inter-company loan; and
o TEP spent $8 million in the first three months of 2004 related to
refinancing its Credit Agreement; partially offset by
o a $52 million increase in repayments on long-term debt related to
TEP's early redemption of First Mortgage Bonds in the first three
months of 2005;
o a $5 million increase in scheduled payments made on capital lease
obligations; and
o an increase of $5 million in other cash payments.
At March 31, 2005, there were no outstanding borrowings under TEP's
revolving credit facility.
Inter-Company Note from UniSource Energy
----------------------------------------
On March 1, 2005, UniSource Energy repaid to TEP a debt obligation in the
principal amount of $95 million plus accrued interest of $11 million. TEP
expects that it will use the proceeds during May 2005 to redeem or repurchase
certain of its existing indebtedness through tender offers and redemptions. See
Bond Issuance and Redemptions, below.
Bond Issuance and Redemptions
-----------------------------
41
TEP made the required sinking fund payment of $1 million on its 6.1% First
Mortgage IDBs in January 2005.
In March 2005, TEP redeemed at par the remaining $31 million of its 6.1%
First Mortgage IDBs, which were due in 2008, as well as the remaining $21
million of its 7.5% First Mortgage IDBs, which were due in 2006.
Pursuant to a recently expired tender offer, TEP has agreed to purchase
$147 million of its 1997 Pima Series B and $74 million of its 1997 Pima Series C
fixed-rate tax-exempt debt obligations from bondholders on May 11, 2005, at a
price of $101.50 per $100 principal amount. Additionally, TEP will redeem at par
$4 million of bonds not tendered on May 18, 2005. Upon completion of these
purchases and redemptions in the principal amount of $225 million, TEP expects
the ratio of equity to total capitalization (excluding capital leases) will
improve to 40%, thereby allowing TEP to dividend up to 100% of its current year
net income to UniSource Energy.
Capital Lease Obligations
-------------------------
At March 31, 2005, TEP had $712 million of total capital lease obligations
on its balance sheet. The table below provides a summary of the outstanding
lease amounts.
BALANCE AT
LEASED ASSET 03/31/2005 EXPIRATION
---------------------------------------- --------------------------- ---------------------
- In Millions -
Springerville Unit 1 $427 2014
Springerville Coal Handling Facilities 126 2015
Springerville Common Facilities 104 2020
Sundt Unit 4 54 2010
Other Leases 1 2006
---------------------------------------- --------------------------- ---------------------
Total Capital Lease Obligations $712
======================================== =========================== =====================
Except for TEP's 13% equity interest in the Springerville Coal Handling
Facilities, TEP will not own these assets at the expiration of the leases. TEP
may renew the leases or purchase the leased assets at such time. These renewal
and purchase options are generally for fair market value as determined at that
time.
TEP Credit Agreement
--------------------
On May 4, 2005, TEP entered into a new $401 million Credit Agreement (TEP
Credit Agreement) to replace its previous $401 million credit agreement. The TEP
Credit Agreement includes a $60 million revolving credit facility and a $341
million letter of credit facility to support $329 million aggregate principal
amount of tax-exempt variable rate bonds. The TEP Credit Agreement expires May
4, 2010 and is secured by $401 million of Second Mortgage Bonds.
Covenants in the TEP Credit Agreement restrict additional indebtedness,
liens and sale of assets and sale-leasebacks agreements. The TEP Credit
Agreement also contains several financial covenants including: (1) a minimum
cash coverage ratio, and (2) a maximum leverage ratio. If TEP complies with the
terms of the TEP Credit Agreement, TEP may pay dividends to UniSource Energy.
Certain regulatory actions may cause a decrease in the amount that may be
borrowed.
The TEP Credit Agreement may become immediately due and payable if an event
of default occurs. An event of default includes failure to make required
payments under the TEP Credit Agreement; change in control, as defined; failure
of TEP or certain subsidiaries to make payments or default on debt greater than
$20 million; or certain bankruptcy events at TEP or certain subsidiaries.
Interest rates and fees under the TEP Credit Agreement are based on a
pricing grid tied to TEP's credit ratings. The letter of credit fees are 0.875%
under the TEP Credit Agreement. Amounts drawn under the letter of credit would
currently bear interest based on LIBOR plus 0.875% per annum. Borrowings under
the revolving credit facility bear interest at a variable interest rate
consisting of a spread over LIBOR or an alternate base rate. The per annum rate
currently in effect on borrowings under TEP's revolving credit facility is LIBOR
plus 0.875%. TEP also pays a commitment fee of 0.20% on the unused portion of
the revolving credit facility.
At May 9, 2005, TEP had no outstanding borrowings under the revolving
credit facility component of the TEP Credit Agreement. However, TEP may
temporarily borrow funds in May 2005 in connection with the repurchase and
42
redemption of $225 million of fixed-rate tax-exempt debt. See UniSource Energy,
Liquidity and Capital Resources, UniSource Energy Credit Agreement, Use of
Proceeds, above, and Bond Issuances and Redemptions, above.
Mortgage Indentures
-------------------
TEP's first mortgage indenture and second mortgage indenture create liens
on and security interests in most of TEP's utility plant assets. Springerville
Unit 2, which is owned by San Carlos Resources Inc, a wholly owned subsidiary of
TEP, is not subject to these liens and security interests. TEP's mortgage
indentures allow TEP to issue additional mortgage bonds on the basis of: (1) a
percentage of net utility property additions and/or (2) the principal amount of
retired mortgage bonds. The amount of bonds that TEP may issue is also subject
to a net earnings test under each mortgage indenture.
TEP's Credit Agreement contains limits on the amount of First and Second
Mortgage Bonds that may be outstanding. The TEP Credit Agreement allows no more
than $138 million of First Mortgage Bonds to be outstanding, and no more than a
total of $650 million in First and Second Mortgage Bonds to be outstanding. At
March 31, 2005, TEP had $138 million of First Mortgage Bonds and a total of $539
million in First and Second Mortgage Bonds outstanding. Although the first and
second mortgage indentures would allow TEP to issue additional bonds based on
property additions and/or retired bond credits, the limits imposed by the TEP
Credit Agreement are more restrictive and are currently the governing
limitations.
Under the terms of the TEP Credit Agreement, TEP has committed to use
commercially reasonable efforts to substitute Second Mortgage Bonds for First
Mortgage Bonds collateralizing the $138 million of First Collateral Trust Bonds
outstanding, and to terminate TEP's First Mortgage Indenture.
CONTRACTUAL OBLIGATIONS
There have been no significant changes in TEP's contractual obligations or
other commercial commitments from those reported in TEP's 2004 Annual Report on
Form 10-K.
DIVIDENDS ON COMMON STOCK
TEP can pay dividends if it maintains compliance with the TEP Credit
Agreement and certain financial covenants. As of March 31, 2005, TEP was in
compliance with the terms of its then existing Credit Agreement.
The ACC Holding Company Order stated that TEP may not pay dividends to
UniSource Energy in excess of 75% of its earnings until TEP's common equity
equals 37.5% of total capitalization (excluding capital lease obligations). The
Citizens Settlement Agreement, as approved by the ACC, modified this dividend
limitation so that it will remain in place until TEP's common equity equals 40%
of total capitalization (excluding capital lease obligations). As of March 31,
2005, TEP's common equity equaled 29.6% of total capitalization (excluding
capital lease obligations).
UniSource Energy expects to borrow the entire $90 million available under
its term loan facility by June 30, 2005 and use the loan proceeds to make a
capital contribution to TEP. It is anticipated that this capital contribution,
together with the proceeds TEP received from the inter-company note repayment in
March 2005 and any additional capital contributions to TEP from the proceeds of
UniSource Energy's issuance of convertible senior notes in March 2005, will be
used by TEP to retire or repurchase $225 million of its outstanding debt
obligations. After these transactions are complete, TEP expects its common
equity ratio to equal 40% of total capitalization (excluding capital leases).
In addition to the dividend limitations noted above, the Federal Power Act
states that dividends shall not be paid out of funds properly included in
capital accounts. Although the terms of the Federal Power Act are unclear, we
believe that there is a reasonable basis to pay dividends from current year
earnings.
43
UNS GAS
RESULTS OF OPERATIONS
- ---------------------
UNS Gas reported net income of $4 million in both the first quarters of
2005 and 2004.
As of March 31, 2005, UNS Gas had approximately 135,600 retail customers, a
5% increase from last year. The table below shows UNS Gas' therm sales and
revenues for the first quarters of 2005 and 2004.
SALES REVENUE
THREE MONTHS ENDED MARCH 31, 2005 2004 2005 2004
-------------------------------------- --------------------------- ---------------------------
- Millions of Therms - - Millions of Dollars -
RETAIL THERM SALES:
Residential 30 31 $ 30 $ 31
Commercial 10 11 9 10
Industrial 1 1 1 1
Public Authorities 3 3 3 2
-------------------------------------- ---------- ---------------- ------------ --------------
TOTAL RETAIL THERM SALES 44 46 43 44
Transport - - 1 1
Negotiated Sales Program (NSP) 5 6 3 4
-------------------------------------- ---------- ---------------- ------------ --------------
TOTAL THERM SALES 49 52 $ 47 $ 49
====================================== ========== ================ ============ ==============
Retail therm sales were 4% lower in the first quarter of 2005 compared with
the same period last year due to mild winter weather. Retail revenues fell $1
million, or 2%, in the first three months of 2005.
Through a Negotiated Sales Program (NSP) approved by the ACC, UNS Gas
supplies natural gas to some of its large transportation customers.
Approximately one half of the margin earned on these NSP sales is retained by
UNS Gas, while the remainder benefits retail customers through a credit to the
Purchased Gas Adjustor (PGA) mechanism which reduces the gas commodity price.
See Factors Affecting Results of Operations, Rates and Regulation, Energy Cost
Adjustment Mechanism, below.
The table below provides summary financial information for UNS Gas.
THREE MONTHS ENDED MARCH 31, 2005 2004
------------------------------------------------- ---------------------------
- Millions of Dollars -
Gas Revenues $ 46 $49
Other Revenues 1 -
------------------------------------------------- ------------ --------------
Total Operating Revenues 47 49
------------------------------------------------- ------------ --------------
Purchased Gas Expense 31 32
------------------------------------------------- ------------ --------------
Other Operations and Maintenance Expense 6 6
Depreciation and Amortization 1 1
Taxes other than Income Taxes 1 1
------------------------------------------------- ------------ --------------
Total Other Operating Expenses 8 8
------------------------------------------------- ------------ --------------
Operating Income 8 9
------------------------------------------------- ------------ --------------
Total Interest Expense 1 2
Income Tax Expense 3 3
------------------------------------------------- ------------ --------------
NET INCOME $ 4 $ 4
================================================= ============ ==============
44
FACTORS AFFECTING RESULTS OF OPERATIONS
- ---------------------------------------
RATES AND REGULATION
ENERGY COST ADJUSTMENT MECHANISM
UNS Gas' retail rates include a PGA mechanism intended to address the
volatility of natural gas prices and allows UNS Gas to recover its costs through
a price adjustor. The PGA charge may be changed monthly based on an ACC approved
mechanism that compares the twelve-month rolling average gas cost to the base
cost of gas, subject to limitations on how much the price per therm may change
in a twelve month period. The difference between the actual cost of UNS Gas' gas
supplies and transportation contracts and that currently allowed by the ACC are
deferred and recovered or repaid through the PGA mechanism. When under or over
recovery trigger points are met, UNS Gas may request a PGA surcharge or
surcredit with the goal of collecting or returning the amount deferred from or
to customers over a twelve month period.
In January 2005, UNS Gas requested the ACC approve a PGA surcharge of $0.06
per therm to begin April 1, 2005 and end one year later, to recover its excess
gas purchase costs. The previous PGA surcharge of $0.1155 per therm took effect
October 1, 2003 and ended November 1, 2004. On March 31, 2005, the ACC approved
a PGA surcharge of $0.03 per therm beginning April 11, 2005 and to last until
the excess gas purchase costs are fully recovered. Based on current and
projected gas prices and the rates currently in effect, we do not expect the PGA
balance at March 31, 2005, to be fully recovered until 2008.
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
UNS Gas' capital requirements consist primarily of capital expenditures. In
the first three months of 2005, capital expenditures were $7 million. During
2005, UNS Gas expects to generate sufficient internal cash flows to fund its
operating activities and a portion of its construction expenditures. Remaining
cash needed for construction expenditures is expected to be obtained through a
combination of the equity investment from UniSource Energy and borrowings under
a revolving credit facility that was established in April 2005. See Credit
Agreement, below.
In January 2005, UNS Gas established a short-term inter-company promissory
note to UniSource Energy, by which it may borrow up to $10 million for general
corporate purposes. On March 10, 2005, UniSource Energy contributed an
additional $6 million in equity to UNS Gas. On March 10, 2005, UNS Gas repaid
the $6 million outstanding on this note from the proceeds of the $6 million
equity contribution.
The table below provides summary information for operating cash flow and
capital expenditures for the first three months of 2005 and 2004.
THREE MONTHS ENDED MARCH 31, 2005 2004
----------------------------------------- -------------------------------
- Millions of Dollars -
Net Cash Flows - Operating Activities $ 6 $ 11
Capital Expenditures 7 4
----------------------------------------- ---------------- --------------
UNS Gas/UNS Electric Revolver
-----------------------------
On April 15, 2005, UNS Gas and UNS Electric, each as a borrower, and UES,
as guarantor, entered into a $40 million three-year unsecured revolving credit
agreement with a group of lenders (the UNS Gas/UNS Electric Revolver). Either
borrower may borrow up to a maximum of $30 million; however, the total combined
amount borrowed can not exceed $40 million. The UNS Gas/UNS Electric Revolver
expires on April 15, 2008. The proceeds of any loans or letters of credit are
expected to be used for general corporate purposes.
UNS Gas is only liable for UNS Gas' borrowings, and similarly, UNS Electric
is only liable for UNS Electric's borrowings under the UNS Electric/UNS Gas
Revolver. UES guarantees the obligations of both UNS Gas and UNS Electric.
Interest is payable at LIBOR plus 1.50%; or at a rate equal to the sum of:
(1) the greater of the federal funds rate plus 1/2 of 1% or a bank reference
rate, and (2) 0.50%.
45
The UNS Gas/UNS Electric Revolver contains a number of covenants which
restrict additional indebtedness, liens, mergers and sales of assets. The UNS
Gas/UNS Electric Revolver also contains several financial covenants including:
(1) a maximum consolidated leverage ratio and (2) a minimum cash flow to
interest coverage ratio, in each case determined for each borrower on a
standalone basis.
The UNS Gas/UNS Electric Revolver may become immediately payable if an
event of default occurs. An event of default includes failure to make required
payments under the UNS Gas/UNS Electric Revolver; certain change in control
transactions or certain bankruptcy events of UNS Gas or UNS Electric; or failure
of UES, UNS Gas or UNS Electric to make payments or default on debt greater than
$4 million.
UNS Gas and UNS Electric expect to draw upon the UNS Gas/UNS Electric
Revolver from time to time primarily for seasonal working capital purposes.
Senior Unsecured Notes
----------------------
On August 11, 2003, UNS Gas issued a total of $100 million of aggregate
principal amount of senior unsecured notes in a private placement consisting of
$50 million of 6.23% Notes due in 2011 and $50 million of 6.23% Notes due in
2015. Proceeds from the note issuance were paid to Citizens to purchase the
Arizona gas system assets. The notes are guaranteed by UES.
The note purchase agreement for UNS Gas contains certain restrictive
covenants, including restrictions on transactions with affiliates, mergers,
liens to secure indebtedness, restricted payments, incurrence of indebtedness,
and minimum net worth. Consolidated Net Worth, as defined by the note purchase
agreement for UNS Gas, is approximately equal to the balance sheet line item,
Common Stock Equity. The table below outlines the actual and required minimum
net worth levels of UES and UNS Gas at March 31, 2005.
REQUIRED MINIMUM
COMPANY NET WORTH ACTUAL NET WORTH
--------------------- --------------------------------------------------
- Millions of Dollars -
UES $ 50 $114
UNS Gas 43 69
--------------------- ---------------------------- ---------------------
The incurrence of indebtedness covenant requires UNS Gas to meet certain
tests before additional indebtedness may be incurred. These tests include:
o A ratio of Consolidated Long-Term Debt to Consolidated Total
Capitalization of no greater than 0.65 to 1.00.
o An Interest Coverage Ratio (a measure of cash flow to cover interest
expense) of at least 2.50 to 1.00.
However, UNS Gas may, without meeting these tests, refinance indebtedness
and incur short-term debt in an amount not to exceed $7 million. UNS Gas may not
declare or make distributions or dividends (restricted payments) on its common
stock unless (a) immediately after giving effect to such action no default or
event of default would exist under its note purchase agreement and (b)
immediately after giving effect to such action, it would be permitted to incur
an additional dollar of indebtedness under the debt incurrence test. As of March
31, 2005, UNS Gas was in compliance with the terms of its note purchase
agreement.
The senior unsecured notes may become due earlier than the maturity date
upon the occurrence and continuance of an event of default under the note
purchase agreement. Events of default under the note purchase agreement include:
failure to make payments required by the note purchase agreement; certain events
of bankruptcy or similar liquidation or reorganization proceedings; and a change
of control of UES or UNS Gas.
In addition, an event of default may occur in the following situations: UNS
Gas, UES or UNS Electric defaults on any payments required of certain
indebtedness in an aggregate principal amount of at least $4 million; any such
indebtedness becomes due or is called for payment prior to its scheduled payment
date; or if there is a default in the compliance with the other terms of such
indebtedness and, as a result of such default, such indebtedness has become due
and payable, prior to its scheduled payment date.
46
DIVIDENDS ON COMMON STOCK
The Citizens Settlement Agreement, as approved by the ACC, limits dividends
payable by UNS Gas to 75% of earnings until the ratio of common equity to total
capitalization reaches 40%. An equity investment of $6 million was made to UNS
Gas by UniSource Energy on March 10, 2005. At March 31, 2005, the ratio of
common equity to total capitalization for UNS Gas was 41%.
The note purchase agreement for UNS Gas contains restrictive covenants
including restrictions on dividends. According to the note purchase agreements
UNS Gas may not declare or make distributions or dividends (restricted payments)
on its common stock unless, (a) immediately after giving effect to such action
no default or event of default would exist under its note purchase agreement and
(b) immediately after giving effect to such action, it would be permitted to
incur an additional dollar of indebtedness under the debt incurrence test. It is
unlikely, however, that UNS Gas will pay dividends in the next five years due to
expected cash requirements for capital expenditures.
UNS ELECTRIC
RESULTS OF OPERATIONS
- ---------------------
UNS Electric reported net income of approximately $1 million in the first
quarters of both 2005 and 2004. Similar to TEP's operations, we expect UNS
Electric's operations to be seasonal in nature, with peak energy demand
occurring in the summer months.
As of March 31, 2005, UNS Electric had approximately 86,500 retail
customers, a 5% increase from last year. The table below shows UNS Electric's
kWh sales and revenues for the first quarters of 2005 and 2004.
SALES REVENUE
THREE MONTHS ENDED MARCH 31, 2005 2004 2005 2004
---------------------------------- ------------------------------------- ----------------------------------
- Millions of kWh - - Millions of Dollars -
ELECTRIC RETAIL SALES:
Residential 152 153 $ 16 $ 16
Commercial 122 120 12 12
Industrial 42 43 3 3
Other 1 1 - -
---------------------------------- ----------------- ------------------- ---------------- -----------------
TOTAL ELECTRIC RETAIL SALES 317 317 $ 31 $ 31
================================== ================= =================== ================ =================
Retail kWh sales and revenues were unchanged in the first quarter of 2005
compared with the same period last year. Mild winter weather offset the growth
in retail customers.
47
The table below provides summary financial information for UNS Electric.
THREE MONTHS ENDED MARCH 31, 2005 2004
---------------------------------------------- ---------------------------
- Millions of Dollars -
Electric Revenues $ 31 $ 31
Other Revenues 1 -
---------------------------------------------- ------------ --------------
Total Operating Revenues 32 31
---------------------------------------------- ------------ --------------
Purchased Energy Expense 21 21
---------------------------------------------- ------------ --------------
Other Operations and Maintenance Expense 6 5
Depreciation and Amortization 2 2
Taxes other than Income Taxes 1 1
---------------------------------------------- ------------ --------------
Total Other Operating Expenses 9 8
---------------------------------------------- ------------ --------------
Operating Income 2 2
---------------------------------------------- ------------ --------------
Total Interest Expense 1 1
Income Tax Expense - -
---------------------------------------------- ------------ --------------
NET INCOME $ 1 $ 1
============================================== ============ ==============
FACTORS AFFECTING RESULTS OF OPERATIONS
- ---------------------------------------
COMPETITION
As required by the ACC order approving UniSource Energy's acquisition of
the Citizens' Arizona gas and electric assets, on November 3, 2003, UNS Electric
filed with the ACC a plan to open its service territories to retail competition
by December 31, 2003. The plan addresses all aspects of implementation. It
includes UNS Electric's unbundled distribution tariffs for both standard offer
customers and customers that choose competitive retail access, as well as Direct
Access and Settlement Fee schedules. UNS Electric's direct access rates for both
transmission and ancillary services will be based upon its FERC Open Access
Transmission Tariff. The plan is subject to review and approval by the ACC. As a
result of the court decisions concerning the ACC's Retail Electric Competition
Rules, we are unable to predict when and how the ACC will address this plan. See
Tucson Electric Power Company, Factors Affecting Results of Operations,
Competition, above for information regarding the recent Arizona Court of Appeals
decision.
RATES AND REGULATION
ENERGY COST ADJUSTMENT MECHANISM
UNS Electric's retail rates include a PPFAC, which allows for a separate
surcharge or surcredit to the base rate for delivered purchased power to collect
or return under or over recovery of costs. The ACC has approved a PPFAC
surcharge of $0.01825 per kWh to recover the cost of the current
full-requirements power supply agreement with PWCC. UNS Electric is required to
enter into negotiations with PWCC to potentially reduce the cost of this
purchased power contract; 90% of any savings from the negotiations is to be
passed on to UNS Electric rate payers.
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
UNS Electric's capital requirements consist primarily of capital
expenditures. In the first three months of 2005, capital expenditures were $5
million. During 2005, UNS Electric expects to generate sufficient internal cash
flows to fund its operating activities and a portion of its construction
expenditures. Remaining cash needed for construction expenditures is expected to
be obtained through a combination of the equity investment from UniSource Energy
and borrowings under a revolving credit facility that was established in April
2005.
On March 10, 2005, UniSource Energy contributed an additional $4 million in
equity to UNS Electric.
The table below provides summary information for operating cash flow and
capital expenditures for the first quarters of 2005 and 2004.
48
THREE MONTHS ENDED MARCH 31, 2005 2004
------------------------------------------ -------------------------------
- Millions of Dollars -
Net Cash Flows - Operating Activities $ 7 $ 5
Capital Expenditures 5 4
------------------------------------------ ---------------- --------------
UNS Gas/UNS Electric Revolver
-----------------------------
See UNS Gas, Liquidity and Capital Resources, UNS Gas/UNS Electric Revolver
above for description of UNS Electric's unsecured revolving credit agreement.
Senior Unsecured Notes
----------------------
On August 11, 2003, UNS Electric issued $60 million of aggregate principal
amount of 7.61% senior unsecured notes due in 2008. Proceeds from the note
issuance were paid to Citizens to purchase the Arizona electric system assets.
The notes are guaranteed by UES.
The note purchase agreement for UNS Electric contains certain restrictive
covenants, including restrictions on transactions with affiliates, mergers,
liens to secure indebtedness, restricted payments, incurrence of indebtedness,
and minimum net worth. Consolidated Net Worth, as defined by the note purchase
agreement for UNS Electric, is approximately equal to the balance sheet line
item, Common Stock Equity. The table below outlines the actual and required
minimum net worth levels of UES and UNS Electric at March 31, 2005.
REQUIRED MINIMUM
COMPANY NET WORTH ACTUAL NET WORTH
----------------------- ---------------------------------------------------
- Millions of Dollars -
UES $ 50 $ 114
UNS Electric 26 45
----------------------- --------------------------- -----------------------
The incurrence of indebtedness covenant requires UNS Electric to meet
certain tests before additional indebtedness may be incurred. These tests
include:
o A ratio of Consolidated Long-Term Debt to Consolidated Total
Capitalization of no greater than 0.65 to 1.00.
o An Interest Coverage Ratio (a measure of cash flow to cover interest
expense) of at least 2.50 to 1.00.
However, UNS Electric may, without meeting these tests, refinance
indebtedness and incur short-term debt in an amount not to exceed $5 million.
UNS Electric may not declare or make distributions or dividends (restricted
payments) on its common stock unless (a) immediately after giving effect to such
action no default or event of default would exist under its note purchase
agreement and (b) immediately after giving effect to such action, it would be
permitted to incur an additional dollar of indebtedness under the debt
incurrence test. As of March 31, 2005, UNS Electric was in compliance with the
terms of the note purchase agreement.
The senior unsecured notes may become due earlier than the maturity date
upon the occurrence and continuance of an event of default under the note
purchase agreement. Events of default under the note purchase agreement include:
failure to make payments required by the note purchase agreement; certain events
of bankruptcy or similar liquidation or reorganization proceedings; and a change
of control of UES or UNS Electric.
In addition, an event of default may occur in the following situations: UNS
Electric, UES or UNS Gas defaults on any payments required of certain
indebtedness in an aggregate principal amount of at least $4 million; any such
indebtedness becomes due or is called for payment prior to its scheduled payment
date; or if there is a default in the compliance with the other terms of such
indebtedness and, as a result of such default, such indebtedness has become due
and payable, prior to its scheduled payment date.
DIVIDENDS ON COMMON STOCK
The Citizens Settlement Agreement, as approved by the ACC, limits dividends
payable by UNS Electric to 75% of earnings until the ratio of common equity to
total capitalization reaches 40%. A $4 million equity investment from UniSource
Energy to UNS Electric was made on March 10, 2005. At March 31, 2005, the ratio
of common equity to total capitalization for UNS Electric was 43%.
49
The note purchase agreement for UNS Electric contains restrictive covenants
including restrictions on dividends. According to the note purchase agreements
UNS Electric may not declare or make distributions or dividends (restricted
payments) on its common stock unless, (a) immediately after giving effect to
such action no default or event of default would exist under its note purchase
agreement and (b) immediately after giving effect to such action, it would be
permitted to incur an additional dollar of indebtedness under the debt
incurrence test. It is unlikely, however, that UNS Electric will pay dividends
in the next five years due to expected cash requirements for capital
expenditures.
GLOBAL SOLAR ENERGY, INC.
RESULTS OF OPERATIONS
- ---------------------
UniSource Energy accounts for Global Solar under the consolidation method
and recognizes 100% of Global Solar's losses. Global Solar recognizes expense
when funding is used for research, development and administrative costs. The
table below provides a breakdown of the net losses recorded by Global Solar:
THREE MONTHS ENDED MARCH 31, 2005 2004
------------------------------------------------------- ----------------------------
- Millions of Dollars -
Global Solar
Other Revenues $ - $ 1
Research & Development Contract Expenses & Losses - (1)
Depreciation & Amortization Expense (1) (1)
Administrative & Other Costs (2) (1)
Income Tax Benefits 1 1
------------------------------------------------------- -------------- -------------
Total Global Solar Net Loss $ (2) $ (1)
======================================================= ============== =============
GLOBAL SOLAR COMMITMENTS
It is our intention for UniSource Energy to cease additional funding of
Global Solar. To that end, Millennium plans to seek additional investors for
Global Solar, or sell all or part of its interest, or a combination of both, to
preserve the value of Global Solar. We anticipate that any operating and capital
funding required to maintain Global Solar in the interim will be provided only
out of existing Millennium cash or cash returns from Millennium investments. We
believe such cash and returns will be adequate for that purpose and to fund
Millennium's remaining commitments to Global Solar. Millennium has been
authorized to fund up to an additional $5 million for capital expenditures and
operations at Global Solar. Millennium funded $1.3 million of this commitment
during the first quarter of 2005. Global Solar has $1 million in commitments to
incur future expenses related to government contracts.
OTHER
RESULTS OF OPERATIONS
- ---------------------
Other non-reportable segments consist of UniSource Energy parent company
expenses, which includes interest expense related to the convertible note
offering as previously discussed, income and losses from other Millennium
investments, and income and losses from UED. UniSource Energy parent company
expenses include interest on the convertible notes and interest expense (net of
tax) on a note payable from UniSource Energy to TEP. The note payable was repaid
in March 2005.
The table below summarizes the income and losses for the Other
non-reportable segments:
THREE MONTHS ENDED MARCH 31, 2005 2004
--------------------------------------- ------------------------------
- Millions of Dollars -
Other Millennium Investments $ (1) $ 3
UniSource Energy Parent Company (1) (2)
--------------------------------------- -------------- ---------------
Total Other $ (2) $ 1
======================================= ============== ===============
50
OTHER MILLENNIUM INVESTMENTS
Millennium accounts for its investments under the consolidation method and
the equity method. In some cases, Millennium is an investment's sole provider of
funding. When this is the case, Millennium recognizes 100% of an investment's
losses, because as sole provider of funds it bears all of the financial risk. To
the extent that an investment becomes profitable and Millennium has recognized
losses in excess of its percentage ownership, Millennium will recognize 100% of
an investment's net income until Millennium's recognized losses equal its
ownership percentage of losses.
Results from Other Millennium Investments for the three months ended March
31, 2005 include after-tax losses of less than $1 million each from several of
Millennium's other investments.
Results from Other Millennium Investments for the three months ended March
31, 2004 include after-tax gains of $3 million from Haddington and $1 million
from MicroSat. These gains were partially offset by after-tax losses of less
than $1 million each from several of Millennium's other investments.
CONSOLIDATED MILLENNIUM INVESTMENTS AND COMMITMENTS
Millennium funded $1.5 million in debt commitments to Infinite Power
Solutions, Inc. (IPS) during 2004, and Dow Corning Enterprises, Inc. (DCEI) also
funded its $1 million commitment. Pursuant to the terms of amended promissory
notes with IPS, Millennium and DCEI have the right to convert at any time the
outstanding debt amounts to equity ownership. DCEI holds warrants to purchase
additional preferred shares of IPS that if exercised, could result in
Millennium's ownership of IPS being reduced to as low as 59%. Millennium and
DCEI are continuing to evaluate the ongoing viability of IPS. In the event the
operations of IPS are discontinued, Millennium would recognize an after-tax loss
of less than $1 million.
In April 2005, Millennium, through Advanced Energy Technologies, Inc.,
entered into a transaction with SpringWorks, LLC (SpringWorks) (the investment
arm of Petters Group Worldwide, LLC), Symmorphix, Inc. (Symmorphix) (a
subsidiary of SpringWorks), DCEI, and IPS that included the formation of a new
Delaware corporation, Battco, Inc. (Battco), intended to carry on the current
business of IPS. As its contribution to the transaction, IPS transferred
substantially all of its assets to Battco in exchange for five million shares of
Battco common stock. Symmorphix contributed a royalty-free license to its
technologies and will provide Battco with development work and equipment at
discounted rates, also in exchange for five million shares of Battco common
stock. The transaction further contemplates that SpringWorks, Millennium and
DCEI will contribute a combined total of approximately $9 million to a
subsequent round of Battco preferred stock financing, contingent on the close of
the preferred financing. Battco expects to raise up to $25 million in preferred
stock financing, $16 million of which will be from additional investors.
Millennium committed to fund $3.3 million of the $9 million, of which $0.4
million has already been funded as a secured convertible loan, which is intended
to be converted to shares of Battco preferred stock at the close of the $25
million financing. The remainder of the preferred stock financing will come from
outside investors.
MEG is in the process of winding down its activities and does not expect to
engage in any new activities after 2005. Millennium is in the process of selling
its remaining interest in Nations Energy Corporation (Nations Energy).
Millennium's remaining commitments for other Millennium investments are $4
million to Haddington and $3 million to Valley Ventures.
It is our intention for UniSource Energy to cease making capital
contributions to Millennium. We anticipate that the funding required to fund
Millennium's remaining commitments will be provided only out of existing
Millennium cash or cash returns from Millennium investments. We believe such
cash and returns will be adequate for that purpose and to fund Millennium's
remaining commitments.
CRITICAL ACCOUNTING ESTIMATES
- -----------------------------
In preparing financial statements under Generally Accepted Accounting
Principles (GAAP), management exercises judgment in the selection and
application of accounting principles, including making estimates and
assumptions. UniSource Energy and TEP consider Critical Accounting Estimates to
be those that could result in materially different financial statement results
if our assumptions regarding application of accounting principles were
different. UniSource Energy and TEP describe their Critical Accounting Estimates
below. Other significant accounting policies and recently issued accounting
standards are discussed in the 2004 Annual Report on Form 10-K, Note 1 of Notes
51
to Consolidated Financial Statements - Nature of Operations and Summary of
Significant Accounting Estimates.
ACCOUNTING FOR RATE REGULATION
TEP, UNS Gas and UNS Electric generally use the same accounting policies
and practices used by unregulated companies for financial reporting under GAAP.
However, sometimes these principles, such as the Financial Accounting Standards
Board's (FASB) Statement of Financial Accounting Standards No. 71, Accounting
for the Effects of Certain Types of Regulation (FAS 71), require special
accounting treatment for regulated companies to show the effect of regulation.
For example, in setting TEP, UNS Gas and UNS Electric's retail rates, the ACC
may not allow TEP, UNS Gas or UNS Electric to currently charge their customers
to recover certain expenses, but instead may require that these expenses be
charged to customers in the future. In this situation, FAS 71 requires that TEP,
UNS Gas and UNS Electric defer these items and show them as regulatory assets on
the balance sheet until TEP, UNS Gas and UNS Electric are allowed to charge
their customers. TEP, UNS Gas and UNS Electric then amortize these items as
expense to the income statement as these charges are recovered from customers.
Similarly, certain revenue items may be deferred as regulatory liabilities,
which are also eventually amortized to the income statement as rates to
customers are reduced.
The conditions a regulated company must satisfy to apply the accounting
policies and practices of FAS 71 include:
o an independent regulator sets rates;
o the regulator sets the rates to recover specific costs of delivering
service; and
o the service territory lacks competitive pressures to reduce rates
below the rates set by the regulator.
TEP
In November 1999, upon approval by the ACC of the TEP Settlement Agreement
relating to recovery of TEP's transition costs and standard retail rates, TEP
discontinued application of FAS 71 to its generation operations. TEP's
transmission and distribution regulatory assets, net of regulatory liabilities,
totaled $213 million at March 31, 2005, $24 million of which is not presently
included in the rate base and consequently is not earning a return on
investment. TEP's transmission and distribution regulatory assets, net of
regulatory liabilities, totaled $225 million at December 31, 2004.
TEP continues to apply FAS 71 to its regulated operations, which include
the transmission and distribution portions of its business. TEP regularly
assesses whether it can continue to apply FAS 71 to these operations. If TEP
stopped applying FAS 71 to its remaining regulated operations, it would write
off the related balances of its regulatory assets as an expense and its
regulatory liabilities as income on its income statement. Based on the
regulatory asset balances, net of regulatory liabilities, at March 31, 2005, if
TEP had stopped applying FAS 71 to its remaining regulated operations, it would
have recorded an extraordinary after-tax loss of approximately $129 million.
While regulatory orders and market conditions may affect cash flows, TEP's cash
flows would not be affected if it stopped applying FAS 71 unless a regulatory
order limited its ability to recover the cost of its regulatory assets.
UNS GAS AND UNS ELECTRIC
UNS Gas and UNS Electric's regulatory liabilities, net of regulatory
assets, collectively totaled $5 million at March 31, 2005 and $4 million at
December 31, 2004. UNS Gas and UNS Electric's regulatory assets and liabilities
are included in rate base and consequently are earning a return on investment.
If UNS Gas and UNS Electric stopped applying FAS 71 to their regulated
operations, they would write off the related balances of regulatory assets as an
expense and regulatory liabilities as income on their income statements. Based
on the balances of regulatory liabilities and assets at March 31, 2005, if UNS
Gas and UNS Electric had stopped applying FAS 71 to their regulated operations,
they would have collectively recorded an extraordinary after-tax gain of $3
million. UNS Gas and UNS Electric's cash flows would not be affected if they
stopped applying FAS 71 unless a regulatory order limited their ability to
recover the cost of their regulatory assets.
ACCOUNTING FOR ASSET RETIREMENT OBLIGATIONS
FAS 143, issued by the FASB in June 2001, requires entities to record the
fair value of a liability for a legal obligation to retire an asset in the
period in which the liability is incurred. A legal obligation is a liability
that a party is required to settle as a result of an existing or enacted law,
statute, ordinance or contract. When the liability is initially recorded, the
entity should capitalize a cost by increasing the carrying amount of the related
long-lived asset. Over time, the liability is adjusted to its present value by
52
recognizing accretion expense as an operating expense in the income statement
each period, and the capitalized cost is depreciated over the useful life of the
related asset. Upon settlement of the liability, an entity either settles the
obligation for its recorded amount or incurs a gain or loss if the actual costs
differ from the recorded amount.
TEP
Prior to adopting FAS 143, costs for final removal of all owned generation
facilities were accrued as an additional component of depreciation expense.
Under FAS 143, only the costs to remove an asset with legally binding retirement
obligations will be accrued over time through accretion of the asset retirement
obligation and depreciation of the capitalized asset retirement cost.
TEP has identified legal obligations to retire generation plant assets
specified in land leases for its jointly-owned Navajo and Four Corners
Generating Stations. The land on which these stations reside is leased from the
Navajo Nation. The provisions of the leases require the lessees to remove the
facilities upon request of the Navajo Nation at the expiration of the leases.
TEP also has certain environmental obligations at the San Juan Generating
Station. TEP has estimated that its share of the cost to remove the Navajo and
Four Corners facilities and settle the San Juan environmental obligations will
be approximately $38 million at the date of retirement. No other legal
obligations to retire generation plant assets were identified.
On November 12, 2004, TEP, Phelps Dodge Energy Services, LLC and PNM
Resources, Inc. each purchased from Duke Energy North America, LLC a one-third
interest in a limited liability company which owns the partially constructed
natural gas-fired Luna Energy Facility (Luna) in southern New Mexico. Luna is
designed as a 570-MW combined cycle plant and is expected to be operational by
the summer of 2006. The new owners assumed asset retirement obligations to
remove certain piping and evaporation ponds and to restore the ground to its
original condition. TEP has estimated its share to settle the obligations will
be approximately $2 million at the date of retirement.
TEP has various transmission and distribution lines that operate under land
leases and rights of way that contain end dates and restorative clauses. TEP
operates its transmission and distribution lines as if they will be operated in
perpetuity and would continue to be used or sold without land remediation. As a
result, TEP is not recognizing the costs of final removal of the transmission
and distribution lines in the financial statements. As of March 31, 2005, TEP
had accrued $69 million for the net cost of removal for the interim retirements
from its transmission, distribution and general plant. As of December 31, 2004,
TEP had accrued $67 million for these removal costs. The amount is recorded as a
regulatory liability.
Amounts recorded under FAS 143 are subject to various assumptions and
determinations, such as determining whether a legal obligation exists to remove
assets, estimating the fair value of the costs of removal, estimating when final
removal will occur, and the credit-adjusted risk-free interest rates to be used
to discount future liabilities. Changes that may arise over time with regard to
these assumptions and determinations will change amounts recorded in the future
as expense for asset retirement obligations.
If TEP retires any asset at the end of its useful life, without a legal
obligation to do so, it will record retirement costs at that time as incurred or
accrued. TEP does not believe that the adoption of FAS 143 will result in any
change in retail rates since all matters relating to the rate-making treatment
of TEP's generating assets have been determined pursuant to the TEP Settlement
Agreement.
UES
UES has various transmission and distribution lines that operate under land
leases and rights of way that contain end dates and restorative clauses. UES
operates its transmission and distribution lines as if they will be operated in
perpetuity and would continue to be used or sold without land remediation. As a
result, UES is not recognizing the cost of final removal of the transmission and
distribution lines in the financial statements. UES had accrued $2 million as of
March 31, 2005 and as of December 31, 2004, for the net cost of removal for
interim retirements from its transmission, distribution and general plant. The
amount is recorded as a regulatory liability.
PENSION AND OTHER POST RETIREMENT BENEFIT PLAN ASSUMPTIONS
We record plan assets, obligations, and expenses related to pension and
other postretirement benefit plans based on actuarial valuations. These
valuations include key assumptions on discount rates, expected returns on plan
assets, compensation increases and health care cost trend rates. These actuarial
53
assumptions are reviewed annually and modified as appropriate. The effect of
modifications is generally recorded or amortized over future periods. We believe
that the assumptions used in recording obligations under the plans are
reasonable based on prior experience, market conditions and the advice of plan
actuaries.
TEP
TEP discounted its future pension plan obligations at December 31, 2004
using rates of 6.1% for its Salaried and Union Plans and 6.0% for its Excess
Benefit Plan. The discount rate used at December 31, 2003 was 6.25% for all
plans. TEP discounted its other postretirement plan obligations using a rate of
5.9% at December 31, 2004, compared with 5.5% at December 31, 2003. TEP
determines the discount rate annually based on the rates currently available on
high-quality, long-term bonds. TEP looks to bonds that receive one of the two
highest ratings given by a recognized rating agency whose future cash flows
match the timing and amount of expected future benefit payments.
The pension liability and future pension expense both increase as the
discount rate is reduced. A decrease in the discount rate results in an increase
in the Projected Benefit Obligation (PBO) and the service cost component of
pension expense. Additionally, the recognized actuarial loss is significantly
impacted by a reduction in the discount rate. Since the PBO increases with the
decrease in discount rate, the obligation is that much larger than would
normally occur due to normal growth of the plan. This leads to an actuarial loss
(or a greater actuarial loss than would occur in the absence of the discount
rate change), which is amortized over future periods leading to a greater
expense. The resulting change in the interest cost component of pension expense
is dependent on the effect that the change in the discount rate has on the PBO
and will vary based on employee demographics. The effect of the lower rate used
to calculate the interest cost is offset to some degree by a larger obligation.
The relative magnitude of these two changes determines whether interest cost
will increase or decrease. For TEP's pension plans, a 25 basis point decrease in
the discount rate would increase the accumulated benefit obligation (ABO) by
approximately $5 million and the related plan expense for 2005 by approximately
$1 million. A similar increase in the discount rate would decrease the ABO by
approximately $5 million and the related plan expense for 2005 by approximately
$1 million. For TEP's plan for other postretirement benefits, a 25 basis point
change in the discount rate would increase or decrease the accumulated
postretirement benefit obligation (APBO) by approximately $2 million. A 25 basis
point change in the discount rate would not have a significant impact on the
related plan expense for 2005.
TEP calculates the market-related value of plan assets using the fair value
of plan assets on the measurement date. TEP assumed that its plans' assets would
generate a long-term rate of return of 8.5% at December 31, 2004 and 8.75% at
December 31, 2003. In establishing its assumption as to the expected return on
plan assets, TEP reviews the plans' asset allocation and develops return
assumptions for each asset class based on advice from an investment consultant
and the plans' actuary that includes both historical performance analysis and
forward looking views of the financial markets. Pension expense increases as the
expected rate of return on plan assets decreases. A 25 basis point change in the
expected return on plan assets would not have a significant impact on pension
expense for 2005.
TEP used an initial health care cost trend rate of 11.0% in valuing its
postretirement benefit obligation at December 31, 2004. This rate reflects both
market conditions and the plan's experience. Assumed health care cost trend
rates have a significant effect on the amounts reported for health care plans. A
1% increase in assumed health care cost trend rates would increase the
postretirement benefit obligation by approximately $5 million and the related
plan expense by approximately $1 million. A similar decrease in assumed health
care cost trend rates would decrease the postretirement benefit obligation by
approximately $4 million and the related plan expense by less than $1 million.
TEP recorded a minimum pension liability in Other Comprehensive Income of
approximately $20 million at December 31, 2004, compared with $3 million at
December 31, 2003. This increase resulted primarily from changes in actuarial
assumptions including revised retirements rates, updated mortality rates and a
reduction in the assumed discount rate.
Based on the above assumptions, TEP will record pension expense of
approximately $10 million and other postretirement benefit expense of $7 million
ratably throughout 2005. TEP will make required pension plan contributions of $6
million in 2005. TEP's other postretirement benefit plan is not funded. TEP
expects to make benefit payments to retirees under the postretirement benefit
plan of approximately $3 million in 2005.
54
UNS GAS AND UNS ELECTRIC
Concurrent with the acquisition of the Arizona gas and electric system
assets from Citizens on August 11, 2003, UES established a pension plan for
substantially all employees of UNS Gas and UNS Electric. UES did not assume the
pension obligation for employees' years of service with Citizens.
UES discounted its future pension plan obligations using a rate of 6.1% at
December 31, 2004 and 6.25% at December 31, 2003. For UES' pension plan, a 25
basis point change in the discount rate would have minimal effect on either the
ABO or the related pension expense. UES recorded a minimum pension liability and
an offsetting Intangible Asset of less than $1 million at December 31, 2004 and
approximately $1 million at December 31, 2003. UES will record pension expense
of $1 million in 2005. UES will make a pension plan contribution of $1 million
in 2005.
On the acquisition date, UES assumed the obligation to provide
postretirement benefits for a small population of former Citizens employees,
both active and retired. The plan is not funded. UES discounted its other
postretirement plan obligations using a rate of 5.9% at December 31, 2004,
compared with 5.5% at December 31, 2003. Postretirement medical benefit expenses
are insignificant to UES' operations.
ACCOUNTING FOR DERIVATIVE INSTRUMENTS, TRADING ACTIVITIES AND
HEDGING ACTIVITIES
A derivative financial instrument or other contract derives its value from
another investment or designated benchmark. TEP enters into forward contracts to
purchase or sell a specified amount of capacity or energy at a specified price
over a given period of time, typically for one month, three months, or one year,
within established limits to take advantage of favorable market opportunities.
In general, TEP enters into forward purchase contracts when market conditions
provide the opportunity to purchase energy for its load at prices that are below
the marginal cost of its supply resources or to supplement its own resources
(e.g., during plant outages and summer peaking periods). TEP enters into forward
sales contracts when it forecasts that it has excess supply and the market price
of energy exceeds its marginal cost. The majority of TEP's forward contracts are
considered to be normal purchases and sales and, therefore, are not required to
be marked to market. However, some of these forward contracts are considered to
be derivatives, which TEP marks to market by recording unrealized gains and
losses and adjusting the related assets and liabilities on a monthly basis to
reflect the market prices at the end of the month.
TEP has a natural gas supply agreement under which it purchases all of its
gas requirements at spot market prices from Southwest Gas Corporation (SWG). TEP
also has agreements to purchase power that are priced using spot market gas
prices. These contracts meet the definition of normal purchases and are not
required to be marked to market. During 2004 and early 2005, in an effort to
minimize price risk on these purchases, TEP entered into commodity price swap
agreements under which TEP purchases gas at fixed prices and simultaneously
sells gas at spot market prices. The spot market price in the swap agreements is
tied to the same index as the purchases under the SWG and purchased power
contracts. These swap agreements, which expire during the summer months through
2007, were entered into with the goal of locking in fixed prices on at least 45%
and not more than 80% of TEP's expected summer monthly gas risk prior to
entering into the month. The swap agreements are marked to market on a monthly
basis; however, since the agreements satisfy the requirements for cash flow
hedge accounting, the unrealized gains and losses are recorded in Other
Comprehensive Income, a component of Common Stock Equity, rather than being
reflected in the income statement. As the gains and losses on these cash flow
hedges are realized, a reclassification adjustment is recorded in Other
Comprehensive Income for realized gains and losses that are included in Net
Income.
TEP manages the risk of counterparty default by performing financial credit
reviews, setting limits, monitoring exposures, requiring collateral when needed,
and using a standardized agreement which allows for the netting of current
period exposures to and from a single counterparty.
UNS Gas and UNS Electric do not currently have any contracts that are
required to be marked to market. UNS Gas does have a natural gas supply and
management agreement under which it purchases substantially all of its gas
requirements at market prices from BP Energy Company (BP). However, the contract
terms allow UNS Gas to lock in fixed prices on a portion of its gas purchases by
entering into fixed price forward contracts with BP at various times during the
year. This enables UNS Gas to provide more stable prices to its customers. These
purchases are made up to three years in advance with the goal of locking in
fixed prices on at least 45% and not more than 80% of the expected monthly gas
consumption prior to entering into the month. These forward contracts, as well
55
as the main gas supply contract, meet the definition of normal purchases and
therefore are not required to be marked to market.
MEG, a wholly-owned subsidiary of Millennium, enters into swap agreements,
options and forward contracts relating to Emissions Allowances and coal. MEG
marks its trading contracts to market by recording unrealized gains and losses
and adjusting the related assets and liabilities on a monthly basis to reflect
the market prices at the end of the month. In accordance with UniSource Energy's
intention to cease making capital contributions to Millennium, Millennium has
significantly reduced the holdings and activity of MEG. MEG is in the process of
winding down its activities and will not engage in any new activities after
2005.
The market prices used to determine fair values for TEP and MEG's
derivative instruments at March 31, 2005 are estimated based on various factors
including broker quotes, exchange prices, over the counter prices and time
value. For TEP's forward power contracts, a 10% decrease in market prices would
result in a decrease in unrealized gains of less than $1 million, while a 10%
increase in market prices would result in an increase in unrealized gains of
less than $1 million. For TEP's gas swap agreements, a 10% decrease in market
prices would result in a $4 million decrease in unrealized gains reported in
Other Comprehensive Income, while a 10% increase in market prices would result
in a $4 million increase in unrealized gains reported in Other Comprehensive
Income. For MEG's remaining trading contracts, a 10% decrease in market prices
would result in an increase in unrealized losses of less than $1 million, while
a 10% increase in market prices would result in a decrease in unrealized losses
of less than $1 million.
Because of the complexity of derivatives, the FASB established a
Derivatives Implementation Group (DIG). To date, the DIG has issued more than
100 interpretations to provide guidance in applying Statement of Financial
Accounting Standards No. 133, Accounting for Derivative Instruments and Hedging
Activities (FAS 133). As the DIG or the FASB continues to issue interpretations,
TEP, UNS Gas and UNS Electric may change the conclusions they have reached and,
as a result, the accounting treatment and financial statement impact could
change in the future.
See Market Risks - Commodity Price Risk in Item 3.
UNBILLED REVENUE - TEP, UNS GAS AND UNS ELECTRIC
TEP's, UNS Gas's and UNS Electric's retail revenues include an estimate of
MWhs/therms delivered but unbilled at the end of each period. Unbilled revenues
are dependent upon a number of factors that require management's judgment
including estimates of retail sales and customer usage patterns. The unbilled
revenue is estimated by comparing the estimated MWhs/therms delivered to the
MWhs/therms billed to TEP, UNS Gas and UNS Electric retail customers. The excess
of estimated MWhs/therms delivered over MWhs/therms billed is then allocated to
the retail customer classes based on estimated usage by each customer class.
TEP, UNS Gas and UNS Electric then record revenue for each customer class based
on the various bill rates for each customer class. Due to the seasonal
fluctuations of TEP's actual load, the unbilled revenue amount increases during
the spring and summer months and decreases during the fall and winter months.
The unbilled revenue amount for UNS Gas sales increases during the fall and
winter months and decreases during the spring and summer months, whereas, the
unbilled revenue amount for UNS Electric sales increases during the spring and
summer months and decreases during the fall and winter months.
PLANT ASSET DEPRECIABLE LIVES - TEP, UNS GAS AND UNS ELECTRIC
We calculate depreciation expense based on our estimate of the useful lives
of our plant assets. The estimated useful lives, and resulting depreciation
rates used to calculate depreciation expense for the transmission and
distribution businesses of TEP, UNS Gas and UNS Electric have been approved by
the ACC in prior rate decisions. Depreciation rates for transmission and
distribution cannot be changed without ACC approval.
The estimated remaining useful lives of TEP's generating facilities are
based on management's best estimate of the economic life of the units. These
estimates are based on engineering estimates, economic analysis, and statistical
analysis of TEP's past experience in maintaining the stations. For 2004,
depreciation expense related to generation assets was $35 million, and our
generation assets are currently depreciated over periods ranging from 23 to 70
years from the original in-service dates.
During the first quarter of 2004, TEP engaged an independent third party to
review the economic estimated useful lives of its owned generating assets in
Springerville, Arizona. TEP then hired a different independent third party to
perform a depreciation study for its generation assets, taking into
56
consideration the newly determined economic useful life for the Springerville
assets, and changes in generation plant life information used by the operators
and other participants of the joint power plants in which TEP participates. As a
result of these analyses, TEP lengthened the useful lives of various generation
assets for periods ranging from 11 to 22 years in July 2004. Consequently,
depreciation rates and the corresponding depreciation expense have been revised
prospectively to reflect the life extensions. The annual impact of these changes
in depreciation rates is a reduction in depreciation expense of $9 million. A
study is currently underway by the operating agent of the San Juan Generating
Station to determine whether San Juan's economic useful life has changed from
previous estimates. If the economic life of San Juan is extended by ten years,
TEP's annual depreciation expense would decrease by an additional $4 million.
DEFERRED TAX VALUATION - TEP AND MILLENNIUM
We record deferred tax liabilities for amounts that will increase income
taxes on future tax returns. We record deferred tax assets for amounts that
could be used to reduce income taxes on future tax returns. We record a
valuation allowance, or reserve, for the deferred tax asset amount that we may
not be able to use on future tax returns. We estimate the valuation allowance
based on our interpretation of the tax rules, prior tax audits, tax planning
strategies, scheduled reversal of deferred tax liabilities, and projected future
taxable income.
At March 31, 2005 and December 31, 2004, UniSource Energy and TEP had a
valuation allowance of $8 million relating to net operating loss (NOL) and
investment tax credit (ITC) carryforward amounts.
Of the $8 million valuation allowance balance at March 31, 2005 and
December 31, 2004, $7 million relates to losses generated by the Millennium
entities. In the future, if UniSource Energy and the Millennium entities
determine that all or a portion of the losses may be used on tax returns, then
UniSource Energy and the Millennium entities would reduce the valuation
allowance and recognize a tax benefit of up to $7 million. The primary factor
that could cause the Millennium entities to recognize a tax benefit would be a
change in expected future taxable income.
The remaining $1 million of valuation allowance balance at March 31, 2005
and December 31, 2004, relates to ITC carryforwards at TEP which may not be
utilized on tax returns prior to their expiration. If in the future UniSource
Energy and TEP determine that it is probable that TEP will not use all or a
portion of additional ITC carryforward amounts, then UniSource Energy and TEP
would record additional valuation allowance and recognize tax expense. The
primary factor that could cause TEP to record additional valuation allowance
would be a change in expected future taxable income.
As of March 31, 2005 and December 31, 2004, UniSource Energy's deferred
income tax assets include $14 million related to unregulated investment losses
of Millennium. TEP's deferred income tax assets include $1 million related to
TEP's unregulated investment losses. These losses have not been reflected on
UniSource Energy's consolidated income tax returns. If UniSource Energy is
unable to recognize such losses through its consolidated income tax return in
the foreseeable future, UniSource Energy and TEP would be required to write off
these deferred tax assets. Millennium intends to restructure its ownership in
two of these investments, Infinite Power Solutions (IPS) and Corporacion Panama
de Energia S.A. (Copesa), in 2005. As a result of these actions, UniSource
Energy expects to liquidate IPS for tax purposes and dispose of its stock
interest in Copesa, both resulting in taxable losses that will be reflected on
UniSource Energy's consolidated income tax return. If these actions, or other
actions resulting in the recognition of the losses for tax purposes, do not
occur, UniSource Energy would be required to eliminate the deferred tax assets
and recognize additional tax expense of $9 million.
NEW ACCOUNTING PRONOUNCEMENTS
- -----------------------------
The FASB recently issued the following Statements of Financial Accounting
Standards (FAS), FASB Interpretations (FIN), and FASB Staff Positions (FSP):
o FIN 47, Accounting for Conditional Asset Retirement Obligations,
issued March 2005, provides guidance for a legal obligation to perform
an asset retirement activity in which the timing and (or) method of
settlement are conditional on a future event that may or may not be
within the control of the entity. The obligation to perform the asset
retirement activity is unconditional even though uncertainty exists
about the timing and (or) method of settlement. FIN 47 requires a
liability be recognized for the fair value of a conditional asset
retirement obligation if the fair value can be reasonably estimated.
FIN 47 is required to be applied by December 31, 2005. We are
57
evaluating the impact on our financial position and results of
operations of the adoption of FIN 47.
o FSP FIN 46(R)-5, Implicit Variable Interests under FASB Interpretation
No. 46 (revised December 2003), Consolidation of Variable Interest
Entities, issued March 2005, addresses whether a reporting enterprise
should consider whether it holds an implicit variable interest in a
variable interest entity (VIE) or potential VIE when specific
conditions exist. The guidance in FSP FIN 46(R)-5 was effective April
1, 2005, and did not have a significant impact on our financial
statements.
o FAS 153, Exchanges of Nonmonetary Assets, issued December 2004,
requires nonmonetary exchanges be accounted for at fair value,
recognizing any gains or losses, if their fair value is determinable
within reasonable limits and the transaction has commercial substance.
A nonmonetary exchange has commercial substance if future cash flows
of the entity are expected to change significantly as a result of the
exchange. FAS 153 is effective for nonmonetary asset exchange
transactions occurring in fiscal periods beginning after June 15,
2005. The adoption of FAS 153 is not expected to have a significant
impact on our financial statements.
o FSP FAS 109-1, Application of FASB Statement No. 109, Accounting for
Income Taxes, to the Tax Deduction on Qualified Production Activities
Provided by the American Jobs Creation Act of 2004, issued in December
2004, provides guidance on the application of FAS 109 to the provision
within the American Jobs Creation Act of 2004 that provides a tax
deduction, beginning in 2005, on qualified production activities,
including a company's electric generation activities. Under FSP FAS
109-1, recognition of the tax deduction on qualified production
activities is ordinarily reported in the year it is earned. FSP FAS
109-1 did not have a significant impact on our financial statements in
the first quarter. We are evaluating the impact of FSP FAS 109-1 on
our financial position and results of operations for the remainder of
the year.
o FAS 151, Inventory Costs, issued November 2004, is an amendment of
Accounting Research Bulletin (ARB) No. 43, Chapter 4, Inventory
Pricing. FAS 151 clarifies that abnormal amounts of idle facility
expense, freight, handling costs, and wasted materials (spoilage)
should be recognized as current-period charges. FAS 151 also requires
the allocation of fixed production overheads to inventory based on the
normal capacity of the production facilities. FAS 151 is effective for
inventory costs incurred during fiscal years beginning after June 15,
2005. The adoption of FAS 151 is not expected to have a significant
impact on our financial statements.
In June 2004, the EITF published Issue No. 03-1, The Meaning of
Other-Than-Temporary Impairment and Its Application to Certain Investments (EITF
03-1). EITF 03-1 provides application guidance on impairment of securities
accounted for under FAS 115, Accounting for Certain Investments in Debt and
Equity Securities, and cost method investments and requires certain quantitative
and qualitative disclosures for securities that are impaired at the balance
sheet date but for which an other-than-temporary impairment has not been
recognized. The disclosure requirements are effective for reporting periods
ending after December 31, 2003. The FASB issued FSP EITF Issue 03-1-1, Effective
Date of Paragraphs 10-20 of EITF Issue No. 03-1, The Meaning of
Other-Than-Temporary Impairment and Its Application to Certain Investments in
September 2004 delaying the effective date of the application guidance on
impairment of securities until the final issuance of FSP EITF Issue 03-1-a. As
of May 9, 2005, a final FSP EITF Issue 03-1-a has not been issued. The adoption
of EITF 03-1 is not expected to have a significant impact on our financial
statements.
SAFE HARBOR FOR FORWARD-LOOKING STATEMENTS
- ------------------------------------------
This Quarterly Report on Form 10-Q contains forward-looking statements as
defined by the Private Securities Litigation Reform Act of 1995. UniSource
Energy and TEP are including the following cautionary statements to make
applicable and take advantage of the safe harbor provisions of the Private
Securities Litigation Reform Act of 1995 for any forward-looking statements made
by or for UniSource Energy or TEP in this Quarterly Report on Form 10-Q.
Forward-looking statements include statements concerning plans, objectives,
goals, strategies, future events or performance and underlying assumptions and
other statements that are not statements of historical facts. Forward-looking
statements may be identified by the use of words such as "anticipates",
"estimates", "expects", "intends", "plans", "predicts", "projects", and similar
expressions. From time to time, we may publish or otherwise make available
forward-looking statements of this nature. All such forward-looking statements,
whether written or oral, and whether made by or on behalf of UniSource Energy or
TEP, are expressly qualified by these cautionary statements and any other
cautionary statements which may accompany the forward-looking statements. In
addition, UniSource Energy and TEP disclaim any obligation to update any
forward-looking statements to reflect events or circumstances after the date of
this report.
Forward-looking statements involve risks and uncertainties, which could
cause actual results or outcomes to differ materially from those expressed in
the forward-looking statements. We express our expectations, beliefs and
projections in good faith and believe them to have a reasonable basis. However,
58
we make no assurances that management's expectations, beliefs or projections
will be achieved or accomplished. We have identified the following important
factors that could cause actual results to differ materially from those
discussed in our forward-looking statements. These may be in addition to other
factors and matters discussed in other parts of this report:
1. Effects of restructuring initiatives in the electric industry and
other energy-related industries.
2. Effects of competition in retail and wholesale energy markets.
3. Changes in economic conditions, demographic patterns and weather
conditions in our retail service areas.
4. Supply and demand conditions in wholesale energy markets, including
volatility in market prices and illiquidity in markets, which are
affected by a variety of factors. These factors include the
availability of generating capacity in the western U.S., including
hydroelectric resources, weather, natural gas prices, the extent of
utility restructuring in various states, transmission constraints,
environmental regulations and cost of compliance, FERC regulation of
wholesale energy markets, and economic conditions in the western U.S.
5. The creditworthiness of the entities with which we transact business
or have transacted business.
6. Changes affecting our cost of providing electrical service including
changes in fuel costs, generating unit operating performance,
scheduled and unscheduled plant outages, interest rates, tax laws,
environmental laws, and the general rate of inflation.
7. Changes in governmental policies and regulatory actions with respect
to financing and rate structures.
8. Changes affecting the cost of competing energy alternatives, including
changes in available generating technologies and changes in the cost
of natural gas.
9. Changes in accounting principles or the application of such principles
to our businesses.
10. Changes in the depreciable lives of our assets.
11. Market conditions and technological changes affecting our unregulated
businesses.
12. Unanticipated changes in future liabilities relating to employee
benefit plans due to changes in market values of retirement plan
assets and health care costs.
13. The outcome of any ongoing or future litigation.
14. Ability to obtain financing through debt and/or equity issuance, which
can be affected by various factors, including interest rate
fluctuations and capital market conditions.
ITEM 3. - QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
- --------------------------------------------------------------------
The information contained in this Item updates, and should be read in
conjunction with, information included in Part II, Item 7A in UniSource Energy
and TEP's Annual Report on Form 10-K for the year ended December 31, 2004, in
addition to the interim condensed consolidated financial statements and
accompanying notes presented in Items 1 and 2 of this Form 10-Q.
We are exposed to various forms of market risk. Changes in interest rates,
returns on marketable securities, and changes in commodity prices may affect our
future financial results. The market risks resulting from changes in interest
rates and returns on marketable securities have not changed materially from the
market risks reported in the 2004 Annual Report on Form 10-K. For additional
information concerning risk factors, including market risks, see Safe Harbor for
Forward-Looking Statements, above.
RISK MANAGEMENT COMMITTEE
We have a Risk Management Committee responsible for the oversight commodity
price risk and credit risk related to the wholesale energy marketing activities
of TEP, the emissions and coal trading activities of MEG, and the fuel and power
59
procurement activities at TEP and UES. Our Risk Management Committee, which
meets on a quarterly basis and as needed, consists of officers from the finance,
accounting, legal, wholesale marketing, transmission and distribution
operations, and the generation operations departments of UniSource Energy. To
limit TEP's, UES' and MEG's exposure to commodity price risk, the Risk
Management Committee sets trading and hedging policies and limits, which are
reviewed frequently to respond to constantly changing market conditions. To
limit TEP's, UES' and MEG's exposure to credit risk, the Risk Management
Committee reviews counterparty credit exposure, as well as credit policies and
limits.
COMMODITY PRICE RISK
We are exposed to commodity price risk primarily relating to changes in the
market price of electricity, natural gas, coal and Emission Allowances.
TEP
To manage its exposure to energy price risk, TEP enters into forward
contracts to buy or sell energy at a specified price and future delivery period.
Generally, TEP commits to future sales based on expected excess generating
capability, forward prices and generation costs, using a diversified market
approach to provide a balance between long-term, mid-term and spot energy sales.
TEP generally enters into forward purchases during its summer peaking period to
ensure it can meet its load and reserve requirements and account for other
contracts and resource contingencies. TEP also enters into limited forward
purchases and sales to optimize its resource portfolio and take advantage of
locational differences in price. These positions are managed on both a
volumetric and dollar basis and are closely monitored using risk management
policies and procedures overseen by the Risk Management Committee. For example,
the risk management policies provide that TEP should not take a short position
in the third quarter and must have owned generation backing up all forward sales
positions at the time the sale is made. TEP's risk management policies also
restrict entering into forward positions with maturities extending beyond the
end of the next calendar year.
The majority of TEP's forward contracts are considered to be "normal
purchases and sales" of electric energy and are not considered to be derivatives
under FAS 133. TEP records revenues on its "normal sales" and expenses on its
"normal purchases" in the period in which the energy is delivered. From time to
time, however, TEP enters into forward contracts that meet the definition of a
derivative under FAS 133. When TEP has derivative forward contracts, it marks
them to market on a daily basis using actively quoted prices obtained from
brokers for power traded over-the-counter at Palo Verde and at other
southwestern U.S. trading hubs. TEP believes that these broker quotations used
to calculate the mark-to-market values represent accurate measures of the fair
values of TEP's positions, because of the short-term nature of TEP's positions,
as limited by risk management policies, and the liquidity in the short-term
market. As of March 31, 2005, all of TEP's derivative forward contracts were for
settlement within 6 months. To adjust the value of its derivative forward
contracts to fair value on its income statement, TEP recorded net unrealized
gains of $0.4 million and $0.2 million on its income statements for the three
month periods ended March 31, 2005 and 2004, respectively.
TEP is also subject to commodity price risk from changes in the price of
natural gas. TEP typically uses generation from its facilities fueled by natural
gas and purchased power, in addition to energy from its coal-fired facilities,
to meet the summer peak demands of its retail customers and to meet local
reliability needs. Some of these purchased power contracts are price indexed to
natural gas prices. Short-term and spot power purchase prices are also closely
correlated to natural gas prices. Due to its increasing seasonal gas and
purchased power usage, TEP hedges a portion of its total natural gas exposure
from plant fuel, gas-indexed purchase power and spot market purchases with fixed
price contracts for a maximum of three years. TEP purchases its remaining gas
fuel needs and purchased power in the spot and short-term markets.
In 2004, the average price of natural gas was $5.44 per MMBtu, or 11%
higher than 2003, due to low gas storage levels and reductions in gas
production. The increase in the regional supply of gas-generated energy and the
completion of a 500-kV transmission connection, in May 2003, however, allowed
TEP to limit its use of its less efficient gas generation units in favor of more
economical purchases of energy in the wholesale market. TEP's generation output
fueled by natural gas was approximately 427,000 MWh, or 4% of total generation
and purchased power in 2004. During 2004, TEP purchased a total of 1,400,000 MWh
of energy, or 11% of total generation and purchased power, of which
approximately 175,000 MWh were from gas-index priced energy under long-term
purchased power contracts with the remainder being from short-term and spot
power markets.
In the first three months of 2005, the average price of natural gas was
$5.55 per MMBtu, or 11% higher than the same period in 2004. TEP's generation
output fueled by natural gas was approximately 56,000 MWh, or 2% of total
60
generation and purchased power in the first quarter of 2005. During the first
quarter of 2005, TEP purchased a total of 268,000 MWh of energy, or 10% of total
generation and purchased power, of which approximately 29,100 MWh were from
gas-index priced energy under long-term purchased power contracts, with the
remainder being from short-term and spot power markets.
In January 2005, TEP entered into a purchased power agreement with Panda
Gila River. TEP will purchase 50 MW of firm energy during June through September
2005.
TEP entered into two purchased power agreements in 2003 for the period 2003
through 2006. During 2003, TEP purchased approximately 125,000 MWh under these
contracts; energy purchased under these agreements is adjusted for changes in
the price of natural gas.
UES
UES is also subject to commodity price risk, primarily from the changes in
the price of natural gas purchased for its UNS Gas customers. This risk is
mitigated through the PGA mechanism in UNS Gas' retail rates which provides an
adjustment to recover the actual costs of gas and transportation. UNS Gas
further reduces this risk by purchasing forward fixed price contracts for a
portion of its projected gas needs under its Price Stabilization Plan. UNS Gas
purchases between 45% and 80% of its estimated gas needs in this manner.
UNS Electric is not exposed to commodity price risk for its purchase of
electricity as it has a fixed price full-requirements supply agreement with PWCC
through May 2008.
MEG
During the fourth quarter of 2001, MEG began managing and trading Emission
Allowances, coal and related instruments. We manage the market risk of this line
of business by setting notional limits by product, as well as limits to the
potential change in fair market value under a 33% change in price or volatility.
We closely monitor MEG's trading activities, which include swap agreements,
options and forward contracts, using risk management policies and procedures
overseen by the Risk Management Committee. MEG marks its trading positions to
market on a daily basis using actively quoted prices obtained from brokers and
options pricing models for positions that extend through 2007. As of March 31,
2005 and December 31, 2004, the fair value of MEG's trading assets combined with
Emission Allowances it holds in escrow was $56.4 million and $76.5 million,
respectively. The fair value of MEG's trading liabilities was $51 million at
March 31, 2005 and $65 million at December 31, 2004. For the three months ended
March 31, 2005, MEG reflected a $2.2 million unrealized loss and $2.5 million
realized gain on its income statement, compared with an unrealized gain of $1.6
million and a realized loss of $1.4 million for the three months ended March 31,
2004.
Unrealized Gain (Loss) of MEG's Trading Activities
- Millions of Dollars -
Maturity 0 - 6 Maturity 6 - 12 Maturity over Total
Source of Fair Value At March 31, 2005 months months 1 yr. Unrealized Gain
(Loss)
- ---------------------------------------------------- ----------------- ------------------ --------------- -----------------
Prices actively quoted $ (6.0) $ - $ - $ (6.0)
Prices based on models and other valuation methods 0.1 - 5.4 5.5
- ---------------------------------------------------- ----------------- ------------------ --------------- -----------------
Total $ (5.9) $ - $ 5.4 $ (0.5)
==================================================== ================= ================== =============== =================
MEG is in the process of winding down its activities and does not expect to
engage in any new activities after 2005.
CREDIT RISK
UniSource Energy is exposed to credit risk in its energy-related marketing
and trading activities related to potential nonperformance by counterparties. We
manage the risk of counterparty default by performing financial credit reviews,
setting limits monitoring exposures, requiring collateral when needed, and using
a standard agreement which allows for the netting of current period exposures to
and from a single counterparty. Despite such mitigation efforts, there is a
potential for defaults by counterparties. In the fourth quarter of 2000 and the
first quarter of 2001, TEP was affected by payment defaults by SCE and PG&E for
amounts owed to the CPX and CISO. In the fourth quarter of 2001, Enron defaulted
on amounts owed to TEP for energy sales.
61
We calculate counterparty credit exposure by adding any outstanding
receivable (net of amounts payable if a netting agreement exists) to the
mark-to-market value of any forward contracts. As of March 31, 2005, TEP's total
credit exposure related to its wholesale marketing activities (excluding
defaulted amounts owed by the CPX, the CISO and Enron), was approximately $21
million and MEG's total credit exposure related to its trading activities was $6
million. TEP and MEG's credit exposure is diversified across approximately 16
counterparties. Approximately $3 million of exposure is to non-investment grade
companies.
UniSource Energy is also exposed to credit risk related to the sale of
assets owned by Nations Energy Corporation (Nations Energy). In September 2001,
Nations Energy sold its 26% equity interest in a power project located in
Curacao, Netherlands Antilles to Mirant Curacao Investments, Ltd. (Mirant
Curacao) a subsidiary of Mirant Corporation (Mirant). Nations Energy received $5
million in cash and an $11 million note receivable from Mirant Curacao. The note
was recorded at its net present value of $8 million using an 8% discount rate,
the discount being recognized as interest income over the five-year life of the
note. As of March 31, 2005, Nations Energy's receivable from Mirant Curacao is
approximately $8 million. The note is primarily included in Investments and
Other Property-Other on UniSource Energy's balance sheet. The first payment of
$2 million on the receivable was received in July 2004. The remaining payments
on the note receivable are expected to be received as follows: $4 million in
July 2005; and $5 million in July 2006. The note is guaranteed by Mirant
Americas, Inc. a subsidiary of Mirant. On July 14, 2003, Mirant, Mirant
Americas, Inc. and various other Mirant companies filed for Chapter 11
bankruptcy protection. Mirant Curacao was not included in the Chapter 11
filings. Based on a review of the projected cash flows for the power project, it
appears Mirant Curacao will have sufficient future cash flows to pay the note
receivable and any applicable interest. However, we cannot predict the ultimate
outcome that Mirant's bankruptcy will have on the collectibility of the note
from Mirant Curacao. Nations Energy will continue to evaluate the collectibility
of the receivable, but currently expects to collect the note in its entirety and
has not recorded any reserve for this note.
ITEM 4. - CONTROLS AND PROCEDURES
- --------------------------------------------------------------------------------
UniSource Energy and TEP have disclosure controls and procedures to ensure
that material information recorded, processed, summarized and reported in their
filings with the SEC is on an accurate and timely basis. Management of UniSource
Energy and TEP, with the participation of the principal executive officer and
principal financial officer of UniSource Energy and TEP, have evaluated these
disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e)
under the Securities Exchange Act of 1934, as amended) as of March 31, 2005.
Based on such evaluation, the principal executive officer and principal
financial officer of UniSource Energy and TEP have concluded that such
disclosure controls and procedures were, as of such date, effective at ensuring
that material information is recorded, processed, summarized and reported
accurately and within the time periods specified by the SEC's rules and forms.
During the fiscal quarter ending March 31, 2005, there have not been any
changes in UniSource Energy or TEP's internal controls over financial reporting
that have materially affected, or are reasonably likely to materially affect,
these controls.
PART II - OTHER INFORMATION
ITEM 1. - LEGAL PROCEEDINGS
- --------------------------------------------------------------------------------
See Item 7. - Management's Discussion and Analysis of Financial Condition
and Results of Operations, Tucson Electric Power Company, Factors Affecting
Operations, for litigation related to ACC orders and retail competition.
We discuss other legal proceedings in Note 6 of Notes to Consolidated
Financial Statements.
CROSS-COMPLAINTS IN WHOLESALE ELECTRICITY ANTITRUST CASES I AND II
62
In late 2000, various California municipalities and citizens filed suits
against Duke Energy Trading and Marketing, L.L.C., Reliant Energy Services, Inc.
and other large suppliers of wholesale electricity alleging that Duke, Reliant,
and the other large suppliers violated antitrust laws by colluding to effect the
price of electricity in the California wholesale electricity market. These
actions were subsequently consolidated in San Diego Superior Court in March 2002
as Wholesale Electricity Antitrust Cases I and II.
Duke and Reliant responded by filing cross-complaints against TEP and
numerous other wholesale electricity market participants in April 2002. The
cross complaints allege that cross-defendants sold power in significant amounts
at prices the antitrust plaintiffs allege were excessive, and as participants in
power sales, cross-defendants are equally liable for plaintiffs alleged damages.
The entire action was removed to the United States District Court for the
Southern District of California in May 2002. The antitrust plaintiffs responded
to the removal by filing a motion for remand, and on December 13, 2002, the
District Court remanded the case back to state court.
Duke and Reliant appealed the District Court's remand order and requested
that the order be stayed pending resolution of their appeal. On December 8,
2004, the Ninth Circuit affirmed the District Court's remand and similarly
denied a subsequent petition for rehearing and motion to recall the mandate. The
mandate has now been issued and the case is in the process of being removed to
state court. Upon remand, TEP expects to file a motion to dismiss the
cross-complaint.
TEP believes these claims are without merit and intends to vigorously
contest them.
CITY OF TACOMA
On June 7, 2004, the City of Tacoma, Washington filed a lawsuit (City of
Tacoma v. American Electric Power Services Corporation, et al. (U.S. District
Ct. W. D. Wash.)) against TEP and various other electricity generators and
marketers alleging that the defendants violated antitrust laws by colluding to
effect the price of electricity in the Pacific Northwest from May 2000 through
2001. These claims are similar to those alleged in the antitrust cases against
TEP and other wholesale electricity market participants described above in
Cross-Complaints in Wholesale Electricity Antitrust Cases I and II. On September
14, 2004, the case was transferred to the United States District Court for the
Southern District of California. TEP along with other defendants filed a joint
motion to dismiss and the motion was granted on February 11, 2005. The City of
Tacoma appealed the dismissal to the Ninth Circuit and the appeal is now
pending.
TEP believes these claims are without merit and intends to vigorously
contest them.
ITEM 5. - OTHER INFORMATION
- --------------------------------------------------------------------------------
TEP CREDIT AGREEMENT
See Item 7. Management's Discussion and Analysis of Financial Condition and
Results of Operations, Tucson Electric Power Company, Liquidity and Capital
Resources, for a description of the TEP Credit Agreement entered into on May 4,
2005.
NON-GAAP MEASURES
ADJUSTED EBITDA
---------------
Adjusted EBITDA represents EBITDA excluding the cumulative effect of
accounting change which is a non-cash item. EBITDA is earnings before interest,
taxes, depreciation and amortization. Adjusted EBITDA is presented here as a
measure of liquidity because it can be used as an indication of a company's
ability to incur and service debt and is commonly used as an analytical
indicator in our industry. Adjusted EBITDA measures presented may not be
comparable to similarly titled measures used by other companies. Adjusted EBITDA
is not a measurement presented in accordance with United States generally
accepted accounting principles (GAAP), and we do not intend Adjusted EBITDA to
represent cash flows from operations as defined by GAAP. Adjusted EBITDA should
not be considered to be an alternative to cash flows from operations or any
other items calculated in accordance with GAAP or an indicator of our operating
performance.
63
UniSource Energy and TEP view Adjusted EBITDA, a non-GAAP financial
measure, as a liquidity measure. The most directly comparable GAAP measure to
Adjusted EBITDA is Net Cash Flows from Operating Activities.
ADJUSTED EBITDA AND NET CASH FLOWS FROM OPERATING ACTIVITIES
THREE MONTHS ENDED MARCH 31,
UNISOURCE ENERGY 2005 2004
- ------------------------------------------------- -----------------------------
- Millions of Dollars -
Adjusted EBITDA $ 80 $ 101
Net Cash Flows from Operating Activities $ 40 $ 44
- ------------------------------------------------- -------------- --------------
THREE MONTHS ENDED MARCH 31,
TEP 2005 2004
- ------------------------------------------------- -----------------------------
- Millions of Dollars -
Adjusted EBITDA $ 71 $ 84
Net Cash Flows from Operating Activities $ 37 $ 36
- ------------------------------------------------- -------------- --------------
RECONCILIATION OF ADJUSTED EBITDA TO CASH FLOWS FROM OPERATIONS
THREE MONTHS ENDED MARCH 31,
UNISOURCE ENERGY 2005 2004
- ------------------------------------------------------------------- -------------- --------------
- Millions of Dollars -
ADJUSTED EBITDA (1) $ 80 $ 101
Amounts from the Income Statements:
Less: Income Taxes (2) 6
Less: Total Interest Expense 40 43
Changes in Assets and Liabilities and Other Non-Cash Items (2) (8)
- ------------------------------------------------------------------- -------------- --------------
NET CASH FLOWS FROM OPERATING ACTIVITIES $ 40 $ 44
=================================================================== ============== ==============
64
THREE MONTHS ENDED MARCH 31,
TEP 2005 2004
- ------------------------------------------------------------- -----------------------------
- Millions of Dollars -
ADJUSTED EBITDA (1) $ 71 $ 84
Amounts from the Income Statements:
Less: Income Taxes (2) 2
Less: Total Interest Expense 37 40
Changes in Assets and Liabilities and Other Non-Cash Items 1 (6)
- ------------------------------------------------------------- -------------- --------------
NET CASH FLOWS FROM OPERATING ACTIVITIES $ 37 $ 36
============================================================= ============== ==============
(1) ADJUSTED EBITDA WAS CALCULATED AS FOLLOWS:
THREE MONTHS ENDED MARCH 31,
UNISOURCE ENERGY 2005 2004
- ------------------------------------------------------------- -----------------------------
- Millions of Dollars -
NET INCOME $ (4) $ 6
Amounts from the Income Statements:
Plus: Income Taxes (2) 6
Plus: Total Interest Expense 40 43
Plus: Depreciation and Amortization 35 35
Plus: Amortization of Transition Recovery Asset 9 9
Plus: Depreciation included in Fuel and Other O&M
Expense (see Note 13 of Notes to Consolidated
Financial Statements) 2 2
- ------------------------------------------------------------- -------------- --------------
ADJUSTED EBITDA $ 80 $ 101
============================================================= ============== ==============
THREE MONTHS ENDED MARCH 31,
TEP 2005 2004
- ------------------------------------------------------------- -----------------------------
- Millions of Dollars -
NET INCOME $ (5) $ 1
Amounts from the Income Statements:
Plus: Income Taxes (2) 2
Plus: Total Interest Expense 37 40
Plus: Depreciation and Amortization 30 30
Plus: Amortization of Transition Recovery Asset 9 9
Plus: Depreciation included in Fuel and Other O&M
Expense (see Note 13 of Notes to Consolidated
Financial Statements) 2 2
- ------------------------------------------------------------- -------------- --------------
ADJUSTED EBITDA $ 71 $ 84
============================================================= ============== ==============
NET DEBT AND TOTAL DEBT AND CAPITAL LEASE OBLIGATIONS - TEP
- -----------------------------------------------------------
Net Debt represents the current and non-current portions of TEP's long-term
debt and capital lease obligations less investment in lease debt. We have
subtracted investment in lease debt because it represents TEP's ownership of the
debt component of its own capital lease obligations. Net Debt measures presented
may not be comparable to similarly titled measures used by other companies. Net
Debt is not a measurement presented in accordance with GAAP and we do not intend
Net Debt to represent debt as defined by GAAP. You should not consider Net Debt
to be an alternative to debt or any other items calculated in accordance with
GAAP.
65
AS OF MARCH AS OF DECEMBER
31, 2005 31, 2004
- ------------------------------------------------------------------------- -------------- -------------------
- Millions of Dollars -
Net Debt $ 1,595 $ 1,684
Total Debt and Capital Lease Obligations $ 1,757 $ 1,855
- ------------------------------------------------------------------------- -------------- -------------------
RECONCILIATION OF TOTAL DEBT AND CAPITAL LEASE OBLIGATIONS TO NET DEBT
AS OF MARCH AS OF DECEMBER
31, 2005 31, 2004
- ------------------------------------------------------------------------- -------------- -------------------
- Millions of Dollars -
Long-Term Debt $ 1,046 $ 1,098
Current Portion - Long-Term Debt - 2
- ------------------------------------------------------------------------- -------------- -------------------
TOTAL DEBT 1,046 1,100
- ------------------------------------------------------------------------- -------------- -------------------
Capital Lease Obligations 655 701
Current Portion - Capital Lease Obligations 56 54
- ------------------------------------------------------------------------- -------------- -------------------
TOTAL DEBT AND CAPITAL LEASE OBLIGATIONS 1,757 1,855
- ------------------------------------------------------------------------- -------------- -------------------
Investment in Lease Debt (162) (171)
- ------------------------------------------------------------------------- -------------- -------------------
NET DEBT $ 1,595 $ 1,684
========================================================================= ============== ===================
RATIO OF EARNINGS TO FIXED CHARGES
- ----------------------------------
The following table reflects the ratio of earnings to fixed charges for
UniSource Energy and TEP:
3 Months Ended 12 Months Ended
March 31, 2005 March 31, 2005
- ------------------------- ---------------------- -------------------------
UniSource Energy 0.88* 1.37
TEP 0.82** 1.46
* UniSource Energy's Ratio of Earnings to Fixed Charges for the 3 months ended
March 31, 2005 is less than one-to-one coverage due to: the seasonal nature of
TEP's business; losses incurred by Global Solar; and losses from other
non-reportable segments. In the first quarter of 2005, TEP incurred a net loss
of $5 million, Global Solar incurred a net loss of $2 million and other
non-reportable segments incurred a net loss of $2 million. The amount of the
deficiency needed to attain a one-to-one coverage would be $4 million.
**TEP's Ratio of Earnings to Fixed Charges for the 3 months ended March 31, 2005
is less than one-to-one coverage as a result of the seasonal nature of TEP's
business. In the first quarter of 2005, TEP incurred a net loss of $5 million.
The amount of the deficiency needed to attain a one-to-one coverage would be $7
million.
SEC REPORTS AVAILABLE ON UNISOURCE ENERGY'S WEBSITE
- ---------------------------------------------------
UniSource Energy and TEP make available their annual reports on Form 10-K,
quarterly reports on Form 10-Q, current reports on Form 8-K, and all amendments
to those reports as soon as reasonably practicable after they electronically
file them with, or furnish them to, the SEC. These reports are available free of
charge through UniSource Energy's website address:
http://www.unisourceenergy.com. A link from UniSource Energy's website to these
SEC reports is accessible as follows: At the UniSource Energy main page, select
Investor Relations from the menu shown at the top of the page; next select SEC
filings from the menu shown on the Investor Relations page.
Information contained at UniSource Energy's website is not part of any
report filed with the SEC by UniSource Energy or TEP.
66
The SEC also maintains an Internet site that contains reports, proxy and
information statements, and other information regarding issuers that file
electronically with the SEC. The SEC website address is http://www.sec.gov.
Interested parties may also read and copy any materials UniSource Energy or TEP
file with the SEC at the SEC's Public Reference Room at 450 Fifth Street, NW,
Washington, DC 20549. Information on the operation of the Public Reference Room
is available by calling the SEC at 1-800-SEC-0030.
ITEM 6. - EXHIBITS
- --------------------------------------------------------------------------------
See Exhibit Index.
67
SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, each
registrant has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized. The signature for each undersigned
company shall be deemed to relate only to matters having reference to such
company or its subsidiaries.
UNISOURCE ENERGY CORPORATION
----------------------------
(Registrant)
Date: May 9, 2005 /s/ Kevin P. Larson
----------------------------------------
Kevin P. Larson
Vice President and Principal
Financial Officer
TUCSON ELECTRIC POWER COMPANY
(Registrant)
Date: May 9, 2005 /s/ Kevin P. Larson
----------------------------------------
Kevin P. Larson
Vice President and Principal
Financial Officer
68
EXHIBIT INDEX
-------------
4(a) -- TEP Credit Agreement, dated as of May 4, 2005, among TEP, the
Lenders Party Thereto, the Issuing Banks Party Thereto,
Union Bank of California, N.A., as Lead Arranger and
Administrative Agent, Wells Fargo Bank, National
Association, as Syndication Agent, and Allied Irish Banks,
P.L.C., as Documentation Agent.
4(b) -- Supplemental Indenture No.6, dated as of May 1, 2005, creating
a series of bonds designated Second Mortgage Bonds,
Collateral Series E.
12(a) -- Computation of Ratio of Earnings to Fixed Charges -
UniSource Energy.
12(b) -- Computation of Ratio of Earnings to Fixed Charges - TEP.
15 -- Letter regarding unaudited interim financial information.
31(a) -- Certification Pursuant to Section 302 of the Sarbanes-Oxley Act -
UniSource Energy, by James S. Pignatelli.
31(b) -- Certification Pursuant to Section 302 of the Sarbanes-Oxley Act -
UniSource Energy, by Kevin P. Larson.
31(c) -- Certification Pursuant to Section 302 of the Sarbanes-Oxley Act -
TEP, by James S. Pignatelli.
31(d) -- Certification Pursuant to Section 302 of the Sarbanes-Oxley Act -
TEP, by Kevin P. Larson.
*32 -- Statements of Corporate Officers (pursuant to Section 906 of the
Sarbanes-Oxley Act of 2002).
*Pursuant to Item 601(b)(32)(ii) of Regulation S-K, this certificate is not
being filed for purposes of Section 18 of the Securities Exchange Act of 1934.
69