- --------------------------------------------------------------------------------
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For The Quarterly Period Ended June 30, 2004
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For The Transition Period From __________ to __________.
Commission 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
----- -----
Tucson Electric Power Company Yes No X
----- -----
At August 18, 2004, 34,264,498 shares of UniSource Energy Corporation's
Common Stock, no par value (the only class of Common Stock), were outstanding.
At August 18, 2004, 32,139,555 shares of Tucson Electric Power
Company's common stock, no par value, were outstanding, of which 32,139,434 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
Page
----
Definitions...................................................................iv
Report of Independent Registered Public Accounting Firm........................1
PART I - FINANCIAL INFORMATION
Item 1. - Financial Statements
UniSource Energy Corporation
Comparative Condensed Consolidated Statements of Income.................2
Comparative Condensed Consolidated Statements of Cash Flows.............3
Comparative Condensed Consolidated Balance Sheets.......................4
Condensed Consolidated Statement of Changes in Stockholders' Equity.....5
Tucson Electric Power Company
Comparative Condensed Consolidated Statements of Income.................6
Comparative Condensed Consolidated Statements of Cash Flows.............7
Comparative Condensed Consolidated Balance Sheets.......................8
Condensed Consolidated Statement of Changes in Stockholders' Equity.....9
Notes to Condensed Consolidated Financial Statements
Note 1. Nature of Operations, Basis of Accounting Presentation and
Equity-Based Compensation.......................................10
Note 2. Proposed Acquisition of UniSource Energy........................14
Note 3. Regulatory Matters..............................................15
Note 4. TEP Credit Facility and Debt Redemption.........................16
Note 5. Accounting Change: Accounting for Asset Retirement
Obligations.....................................................17
Note 6. Accounting for Derivative Instruments and Trading Activities....17
Note 7. Business Segments...............................................18
Note 8. Millennium .....................................................20
Note 9. Commitments and Contingencies...................................22
Note 10. TEP Wholesale Accounts Receivable and Allowances................25
Note 11. UniSource Energy Earnings per Share (EPS).......................25
Note 12. Employee Benefits Plans.........................................26
Note 13. Equity-Based Compensation Plans.................................27
Note 14. Income and Other Taxes..........................................29
Note 15. New Accounting Pronouncements...................................30
Note 16. Supplemental Cash Flow Information..............................31
Note 17. Review by Independent Registered Public Accounting Firm.........32
Item 2. - Management's Discussion and Analysis of Financial Condition and
Results of Operations
Overview of Consolidated Business.........................................33
UniSource Energy Consolidated
Results of Operations..................................................35
Contribution by Business Segment.......................................37
Liquidity and Capital Resources........................................38
Tucson Electric Power Company
Results of Operations..................................................40
Factors Affecting Results of Operations................................44
Liquidity and Capital Resources........................................47
ii
TABLE OF CONTENTS
(concluded)
UniSource Energy Services
Results of Operations..................................................49
Factors Affecting Results of Operations................................51
Liquidity and Capital Resources........................................52
Millennium Energy Holdings, Inc.
Results of Operations..................................................53
Liquidity and Capital Resources........................................54
Critical Accounting Policies..............................................56
New Accounting Pronouncements.............................................62
Safe Harbor for Forward-Looking Statements................................63
Item 3. - Quantitative and Qualitative Disclosures about Market Risk........64
Item 4. - Controls and Procedures...........................................67
PART II - OTHER INFORMATION
Item 1. - Legal Proceedings.................................................68
Item 4. - Submission of Matters to a Vote of Security Holders...............68
Item 5. - Other Information
Additional Financial Data.................................................69
Non-GAAP Measures.........................................................69
SEC Reports Available on UniSource Energy's Website.......................72
Item 6. - Exhibits and Reports on Form 8-K..................................72
Signatures....................................................................73
Exhibit Index.................................................................74
iii
DEFINITIONS
The abbreviations and acronyms used in the 2004 Second 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.
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 the Citizens'
Arizona gas and electric assets.
Common Stock..................... UniSource Energy's common stock, without
par value.
Company or UniSource Energy...... UniSource Energy Corporation.
Cooling Degree Days.............. An index used to measure the impact of
weather on energy usage calculated by
subtracting 75 from the average of the
high and low daily temperatures.
CPX.............................. California Power Exchange.
Credit Agreement................. Credit Agreement between TEP and a
syndicate of lenders, dated as of March
25, 2004.
Emissions Allowance(s)........... An allowance issued by the Environmental
Protection Agency which permits
emission of one ton of sulfur dioxide or
one ton of nitrogen oxide. These
allowances can be bought and sold.
Energy........................... For electricity, the amount of
instantaneous power produced over a
given period of time, measured in MWh.
For natural gas, the high heat value
content of the amount of fuel delivered
over a given period of time, measured in
therms.
FAS 71........................... Statement of Financial Accounting
Standards No. 71: Accounting for the
Effects of Certain Types of Regulation.
FAS 132.......................... Statement of Financial Accounting
Standards No. 132: Employers'
Disclosures about Pensions and Other
Postretirement Benefits.
FAS 133.......................... Statement of Financial Accounting
Standards No. 133: Accounting for
Derivative Instruments and Hedging
Activities.
FAS 143.......................... Statement of Financial Accounting
Standards No. 143: Accounting for Asset
Retirement Obligations.
FAS 149.......................... Statement of Financial Accounting
Standards No. 149: Amendment of
Statement 133 on Derivative Instruments
and Hedging Activities.
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 JPMorgan Chase Bank, successor
trustee, as supplemented and amended.
Four Corners..................... Four Corners Generating Station.
GAAP............................. Generally Accepted Accounting Principles.
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
iv
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.
ITN.............................. ITN Energy Systems, Inc. was formed to
provide research, development, and other
services. Millennium exchanged its
ownership of ITN for increased ownership
of Global Solar and currently owns no
interest in ITN.
ITC.............................. Investment tax credit.
kWh.............................. Kilowatt-hour(s).
kV............................... Kilovolt(s).
LIBOR............................ London Interbank Offered Rate.
MEG.............................. Millennium Environmental 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.
Powertrusion..................... POWERTRUSION International, Inc., a
company owned 77% by Millennium, which
manufactures lightweight utility poles.
PPFAC............................ Purchase Power and Fuel Adjustor Clause.
PWCC............................. Pinnacle West Capital Corporation.
Revolving Credit Facility........ $60 million revolving credit facility
entered into under the Credit
Agreement between a syndicate of banks
and TEP.
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 is Sage Mountain,
L.L.C. and whose limited partners
include investment funds affiliated
with Kohlberg Kravis Roberts & Co.,
L.P., J.P. Morgan Partners, L.L.C.
and Wachovia Capital Partners.
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.
SCE.............................. Southern California Edison Company.
SES.............................. Southwest Energy Solutions, Inc., a
wholly-owned subsidiary of Millennium.
v
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 Unit 1 and 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.
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.
Sundt Generating Station......... H. Wilson Sundt Generating Station
(formerly known as the Irvington
Generating Station).
TEP.............................. Tucson Electric Power Company, the
principal subsidiary of UniSource
Energy.
TEP Settlement Agreement......... TEP's Settlement Agreement approved by the
ACC in November 1999 that provided for
electric retail competition and
transition asset recovery.
Therm............................ A unit of heating value equivalent to
100,000 British thermal units (Btu).
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 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.
vi
Report of Independent Registered Public Accounting Firm
To the Board of Directors and Stockholders of
UniSource Energy Corporation and
to the Board of Directors of
Tucson Electric Power Company:
We have reviewed the accompanying condensed consolidated balance sheets of
UniSource Energy Corporation and its subsidiaries (the Company) and Tucson
Electric Power Company and its subsidiaries (TEP) as of June 30, 2004, and the
related condensed consolidated statements of income for each of the three-month
and six-month periods ended June 30, 2004 and 2003 and the condensed
consolidated statement of cash flows for the six-month periods ended June 30,
2004 and 2003 and the condensed consolidated statement of changes in
stockholders' equity for the six-month period ended June 30, 2004. 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 reviews, 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.
As discussed in Note 1 to the condensed consolidated interim financial
statements, the Company and TEP have restated their financial statements for
unbilled revenues as of June 30, 2003 and for the three-month and six-month
periods ended June 30, 2003.
We previously audited in accordance with the standards of the Public Company
Accounting Oversight Board (United States), the consolidated balance sheet of
the Company and TEP as of December 31, 2003, and the related consolidated
statements of capitalization, of income, of changes in stockholders' equity, and
of cash flows for the year then ended (not presented herein), and in our report
dated February 20, 2004, except as to the restatement of unbilled revenue
described in Note 22, as to which the date is August 19, 2004, we expressed an
unqualified opinion on those consolidated financial statements. In our opinion,
the information set forth in the accompanying condensed consolidated balance
sheets as of December 31, 2003, is fairly stated in all material respects in
relation to the consolidated balance sheet from which it has been derived.
PricewaterhouseCoopers LLP
August 19, 2004
1
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
<table>
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME
Three Months Ended Six Months Ended
June 30, June 30,
2004 2003 Restated 2004 2003 Restated
See Note 1 See Note 1
(Unaudited) (Unaudited)
- -----------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars- - Thousands of Dollars -
Operating Revenues
$ 224,056 $177,237 Electric Retail Sales $ 398,419 $ 306,372
42,189 35,160 Electric Wholesale Sales 83,889 75,444
20,212 - Gas Revenue 69,013 -
3,624 3,676 Other Revenues 8,844 6,504
- -----------------------------------------------------------------------------------------------------------------------
290,081 216,073 Total Operating Revenues 560,165 388,320
- -----------------------------------------------------------------------------------------------------------------------
Operating Expenses
55,340 51,763 Fuel 102,789 98,265
54,350 17,875 Purchased Energy 110,818 33,557
57,646 49,490 Other Operations and Maintenance 124,259 101,646
36,560 30,920 Depreciation and Amortization 71,696 61,440
12,003 7,892 Amortization of Transition Recovery Asset 20,600 11,619
12,611 11,152 Taxes Other Than Income Taxes 25,722 22,743
- -----------------------------------------------------------------------------------------------------------------------
228,510 169,092 Total Operating Expenses 455,884 329,270
- -----------------------------------------------------------------------------------------------------------------------
61,571 46,981 Operating Income 104,281 59,050
- -----------------------------------------------------------------------------------------------------------------------
Other Income (Deductions)
5,013 5,056 Interest Income 9,882 10,290
1,945 1,752 Other Income 10,660 2,794
(4,305) (777) Other Expense (5,321) (3,002)
- -----------------------------------------------------------------------------------------------------------------------
2,653 6,031 Total Other Income (Deductions) 15,221 10,082
- -----------------------------------------------------------------------------------------------------------------------
Interest Expense
20,032 19,113 Long-Term Debt 43,150 38,385
20,065 20,796 Interest on Capital Leases 40,109 41,534
(329) 393 Other Interest Expense, Net of Amounts Capitalized (543) 300
- -----------------------------------------------------------------------------------------------------------------------
39,768 40,302 Total Interest Expense 82,716 80,219
- -----------------------------------------------------------------------------------------------------------------------
Income (Loss) Before Income Taxes and
24,456 12,710 Cumulative Effect of Accounting Change 36,786 (11,087)
11,655 5,790 Income Tax Expense (Benefit) 17,564 (2,882)
- ------------------------------------------------------------------------------------------------------------------------
12,801 6,920 Income (Loss) Before Cumulative Effect of Accounting Change 19,222 (8,205)
- - Cumulative Effect of Accounting Change - Net of Tax - 67,471
- -----------------------------------------------------------------------------------------------------------------------
$ 12,801 $ 6,920 Net Income $ 19,222 $ 59,266
=======================================================================================================================
34,392 33,821 Weighted-average Shares of Common Stock Outstanding (000) 34,288 33,780
=======================================================================================================================
Basic Earnings per Share
$0.37 $0.20 Income (Loss) Before Cumulative Effect of Accounting Change $0.56 $(0.25)
- - Cumulative Effect of Accounting Change - Net of Tax - 2.00
- -----------------------------------------------------------------------------------------------------------------------
$0.37 $0.20 Net Income $0.56 $1.75
=======================================================================================================================
Diluted Earnings per Share
$0.37 $0.20 Income (Loss) Before Cumulative Effect of Accounting Change $0.55 $(0.25)
- - Cumulative Effect of Accounting Change - Net of Tax - 2.00
- -----------------------------------------------------------------------------------------------------------------------
$0.37 $0.20 Net Income $0.55 $1.75
=======================================================================================================================
$0.16 $0.15 Dividends Paid per Share $0.32 $0.30
=======================================================================================================================
<fn>
See Notes to Condensed Consolidated Financial Statements.
</fn>
</table>
2
<table>
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Six Months Ended
June 30,
2004 2003
(Unaudited)
- -----------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
Cash Flows from Operating Activities
Cash Receipts from Electric Retail Sales $ 409,934 $ 314,427
Cash Receipts from Electric Wholesale Sales 108,665 106,983
Cash Receipts from Gas Sales 89,645 -
Other Cash Receipts 3,789 2,406
MEG Cash Receipts from Trading Activity 73,405 44,699
Interest Received 11,042 11,400
Income Tax Refunds Received 286 -
Performance Deposits 1,456 (7,233)
Deposit - Second Mortgage Indenture 17,040 -
Fuel Costs Paid (92,935) (100,507)
Purchased Energy Costs Paid (130,138) (53,894)
Wages Paid, Net of Amounts Capitalized (48,973) (40,709)
Payment of Other Operations and Maintenance Costs (73,156) (55,575)
MEG Cash Payments for Trading Activity (73,096) (40,346)
Capital Lease Interest Paid (41,576) (43,314)
Taxes Paid, Net of Amounts Capitalized (70,589) (49,442)
Interest Paid, Net of Amounts Capitalized (38,821) (36,696)
Income Taxes Paid (8,152) (4,616)
Other 367 (3,300)
- -----------------------------------------------------------------------------------------------------------------------
Net Cash Flows - Operating Activities 138,193 44,283
- -----------------------------------------------------------------------------------------------------------------------
Cash Flows from Investing Activities
Capital Expenditures (70,588) (68,514)
Investment in and Loans to Equity Investees (424) (1,377)
Return of Investment from Millennium Energy Businesses 9,714 -
Proceeds from Investment in Springerville Lease Debt and Equity 8,054 8,778
Payments for Investment in Springerville Lease Debt and Equity (4,499) -
Other 515 (1,177)
- -----------------------------------------------------------------------------------------------------------------------
Net Cash Flows - Investing Activities (57,228) (62,290)
- -----------------------------------------------------------------------------------------------------------------------
Cash Flows from Financing Activities
Proceeds from Borrowings under Revolving Credit Facility 20,000 20,000
Payments on Borrowings under the Revolving Credit Facility (20,000) -
Proceeds from Issuance of Short-Term Debt - 670
Repayments of Short-Term Debt - (460)
Repayments of Long-Term Debt (1,232) (1,286)
Payment of Debt Issue Costs (9,190) (370)
Payments on Capital Lease Obligations (43,641) (38,186)
Common Stock Dividends Paid (10,909) (10,090)
Other 12,006 1,672
- -----------------------------------------------------------------------------------------------------------------------
Net Cash Flows - Financing Activities (52,966) (28,050)
- -----------------------------------------------------------------------------------------------------------------------
Net Increase (Decrease) in Cash and Cash Equivalents 27,999 (46,057)
Cash and Cash Equivalents, Beginning of Year 101,266 90,928
- -----------------------------------------------------------------------------------------------------------------------
Cash and Cash Equivalents, End of Period $ 129,265 $ 44,871
=======================================================================================================================
<fn>
See Note 16 for supplemental cash flow information.
See Notes to Condensed Consolidated Financial Statements.
</fn>
</table>
3
<table>
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED BALANCE SHEETS
December 31,
June 30, 2003 Restated
2004 See Note 1
(Unaudited)
- -----------------------------------------------------------------------------------------------------------------------
- Thousands of Dollars -
ASSETS
Utility Plant
Plant in Service $ 2,958,439 $ 2,899,305
Utility Plant under Capital Leases 748,239 748,239
Construction Work in Progress 105,328 105,804
- -----------------------------------------------------------------------------------------------------------------------
Total Utility Plant 3,812,006 3,753,348
Less Accumulated Depreciation and Amortization (1,310,280) (1,262,962)
Less Accumulated Amortization of Capital Lease Assets (435,746) (421,171)
- -----------------------------------------------------------------------------------------------------------------------
Total Utility Plant - Net 2,065,980 2,069,215
- -----------------------------------------------------------------------------------------------------------------------
Investments and Other Property
Investments in Lease Debt and Equity 174,770 178,789
Other 84,579 109,570
- -----------------------------------------------------------------------------------------------------------------------
Total Investments and Other Property 259,349 288,359
- -----------------------------------------------------------------------------------------------------------------------
Current Assets
Cash and Cash Equivalents 129,265 101,266
Trade Accounts Receivable 116,065 97,904
Unbilled Accounts Receivable 54,226 53,590
Allowance for Doubtful Accounts (15,074) (11,522)
Materials and Fuel Inventory 58,554 58,299
Trading Assets 63,485 21,507
Current Regulatory Assets 9,503 12,129
Deferred Income Taxes - Current 16,872 15,925
Interest Receivable - Current 11,326 11,561
Other 25,891 21,117
- -----------------------------------------------------------------------------------------------------------------------
Total Current Assets 470,113 381,776
- -----------------------------------------------------------------------------------------------------------------------
Regulatory and Other Assets
Transition Recovery Asset 253,582 274,182
Income Taxes Recoverable Through Future Revenues 47,236 49,849
Other Regulatory Assets 13,041 12,327
Other Assets 54,344 46,594
- -----------------------------------------------------------------------------------------------------------------------
Total Regulatory and Other Assets 368,203 382,952
- -----------------------------------------------------------------------------------------------------------------------
Total Assets $ 3,163,645 $ 3,122,302
=======================================================================================================================
CAPITALIZATION AND OTHER LIABILITIES
Capitalization
Common Stock Equity $ 574,114 $ 556,472
Capital Lease Obligations 725,147 762,968
Long-Term Debt 1,285,095 1,286,320
- -----------------------------------------------------------------------------------------------------------------------
Total Capitalization 2,584,356 2,605,760
- -----------------------------------------------------------------------------------------------------------------------
Current Liabilities
Current Obligations under Capital Leases 54,614 50,269
Current Maturities of Long-Term Debt 1,725 1,742
Accounts Payable 72,403 65,745
Interest Accrued 50,580 62,927
Trading Liabilities 60,359 18,753
Taxes Accrued 65,107 50,625
Accrued Employee Expenses 13,793 16,081
Other 22,555 15,839
- -----------------------------------------------------------------------------------------------------------------------
Total Current Liabilities 341,136 281,981
- -----------------------------------------------------------------------------------------------------------------------
Deferred Credits and Other Liabilities
Deferred Income Taxes - Noncurrent 89,292 96,270
Regulatory Liability - Net Cost of Removal for Interim Retirements 65,193 60,998
Other 83,668 77,293
- -----------------------------------------------------------------------------------------------------------------------
Total Deferred Credits and Other Liabilities 238,153 234,561
- -----------------------------------------------------------------------------------------------------------------------
Commitments and Contingencies (Note 9)
- -----------------------------------------------------------------------------------------------------------------------
Total Capitalization and Other Liabilities $ 3,163,645 $ 3,122,302
=======================================================================================================================
See Notes to Condensed Consolidated Financial Statements.
</table>
4
<table>
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)
- In Thousands -
Balances at December 31, 2003 Restated 33,788 $ 668,022 $ (109,706) $ (1,844) $ 556,472
See Note 1
- ------------------------------------------------------------------------------------------------------------------------------------
Comprehensive Income:
2004 Year-to-Date Net Income - - 19,222 - 19,222
Unrealized Gain on Cash Flow Hedges
(net of $961,000 income tax expense) - - - 1,466 1,466
Reclassification of Realized Gain on
Cash Flow Hedges to Net Income
(net of $133,000 income tax expense) - - - (203) (203)
------------
Total Comprehensive Income 20,485
------------
Dividends Declared - (10,909) - (10,909)
Shares Issued under Stock Compensation Plans 64 1,307 - - 1,307
Shares Distributed by Deferred Compensation Trust 1 15 - - 15
Shares Issued for Stock Options 360 6,786 - - 6,786
Other - (42) - - (42)
- ------------------------------------------------------------------------------------------------------------------------------------
Balances at June 30, 2004 34,213 $ 676,088 $ (101,393) $ (581) $ 574,114
====================================================================================================================================
<fn>
* UniSource Energy has 75 million authorized shares of common stock.
See Notes to Condensed Consolidated Financial Statements.
</fn>
</table>
5
<table>
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME
Three Months Ended Six Months Ended
June 30, June 30,
2004 2003 Restated 2004 2003 Restated
See Note 1 See Note 1
(Unaudited) (Unaudited)
- ---------------------------------------------------------------------------------------------------------------------
- Thousands of Dollars - - Thousands of Dollars -
Operating Revenues
$188,908 $177,237 Electric Retail Sales $ 332,084 $ 306,372
42,121 35,160 Electric Wholesale Sales 83,770 75,444
2,713 2,291 Other Revenues 4,862 4,499
- ---------------------------------------------------------------------------------------------------------------------
233,742 214,688 Total Operating Revenues 420,716 386,315
- ---------------------------------------------------------------------------------------------------------------------
Operating Expenses
55,340 51,763 Fuel 102,789 98,265
19,087 17,872 Purchased Power 25,339 33,554
42,576 40,780 Other Operations and Maintenance 90,405 86,081
32,025 29,760 Depreciation and Amortization 62,438 59,384
12,003 7,892 Amortization of Transition Recovery Asset 20,600 11,619
10,442 10,796 Taxes Other Than Income Taxes 21,188 21,946
- ---------------------------------------------------------------------------------------------------------------------
171,473 158,863 Total Operating Expenses 322,759 310,849
- ---------------------------------------------------------------------------------------------------------------------
62,269 55,825 Operating Income 97,957 75,466
- ---------------------------------------------------------------------------------------------------------------------
Other Income (Deductions)
5,000 5,037 Interest Income 9,861 10,204
2,319 2,554 Interest Income - Note Receivable from UniSource Energy 4,639 5,079
1,230 616 Other Income 2,394 1,127
(964) (274) Other Expense (1,900) (539)
- ---------------------------------------------------------------------------------------------------------------------
7,585 7,933 Total Other Income (Deductions) 14,994 15,871
- ---------------------------------------------------------------------------------------------------------------------
Interest Expense
17,257 19,113 Long-Term Debt 37,638 38,385
20,049 20,793 Interest on Capital Leases 40,086 41,527
(310) 314 Other Interest Expense, Net of Amounts Capitalized (499) 67
- ---------------------------------------------------------------------------------------------------------------------
36,996 40,220 Total Interest Expense 77,225 79,979
- ---------------------------------------------------------------------------------------------------------------------
Income Before Income Taxes and
32,858 23,538 Cumulative Effect of Accounting Change 35,726 11,358
14,841 10,027 Income Tax Expense 16,915 5,947
- ---------------------------------------------------------------------------------------------------------------------
18,017 13,511 Income Before Cumulative Effect of Accounting Change 18,811 5,411
- - Cumulative Effect of Accounting Change - Net of Tax - 67,471
- ---------------------------------------------------------------------------------------------------------------------
$ 18,017 $ 13,511 Net Income $ 18,811 $ 72,882
=====================================================================================================================
<fn>
See Notes to Condensed Consolidated Financial Statements.
</fn>
</table>
6
<table>
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Six Months Ended
June 30,
2004 2003
(Unaudited)
- ---------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
Cash Flows from Operating Activities
Cash Receipts from Electric Retail Sales $340,603 $ 314,427
Cash Receipts from Electric Wholesale Sales 108,528 106,983
Interest Received 10,568 11,251
Deposit - Second Mortgage Indenture 17,040 -
Fuel Costs Paid (92,935) (100,507)
Purchased Power Costs Paid (43,047) (53,894)
Wages Paid, Net of Amounts Capitalized (36,799) (32,997)
Payment of Other Operations and Maintenance Costs (55,171) (50,681)
Capital Lease Interest Paid (41,572) (43,306)
Taxes Paid, Net of Amounts Capitalized (48,618) (47,509)
Interest Paid, Net of Amounts Capitalized (33,611) (36,676)
Income Taxes Refunds Received 286 -
Income Taxes Paid (10,002) (3,718)
Other 681 (5)
- ---------------------------------------------------------------------------------------------------------------------
Net Cash Flows - Operating Activities 115,951 63,368
- ---------------------------------------------------------------------------------------------------------------------
Cash Flows from Investing Activities
Capital Expenditures (52,676) (67,450)
Proceeds from Investment in Springerville Lease Debt and Equity 8,054 8,778
Payments for Investment in Springerville Lease Debt and Equity (4,499) -
Other - (1,587)
- ---------------------------------------------------------------------------------------------------------------------
Net Cash Flows - Investing Activities (49,121) (60,259)
- ---------------------------------------------------------------------------------------------------------------------
Cash Flows from Financing Activities
Proceeds from Borrowings under Revolving Credit Facility 20,000 20,000
Payments on Revolving Credit Facility (20,000) -
Repayments of Long-Term Debt (1,225) (1,225)
Payments on Capital Lease Obligations (43,599) (38,134)
Payment of Debt Issue Costs (8,814) (370)
Dividend Paid to UniSource Energy (7,000) (15,000)
Other 9,980 1,685
- ---------------------------------------------------------------------------------------------------------------------
Net Cash Flows - Financing Activities (50,658) (33,044)
- ---------------------------------------------------------------------------------------------------------------------
Net Increase (Decrease) in Cash and Cash Equivalents 16,172 (29,935)
Cash and Cash Equivalents, Beginning of Year 65,262 55,778
- ---------------------------------------------------------------------------------------------------------------------
Cash and Cash Equivalents, End of Period $ 81,434 $ 25,843
- ---------------------------------------------------------------------------------------------------------------------
<fn>
See Note 16 for supplemental cash flow information.
See Notes to Condensed Consolidated Financial Statements.
</fn>
</table>
7
<table>
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED BALANCE SHEETS
June 30, December 31,
2004 2003 Restated
See Note 1
(Unaudited)
- ---------------------------------------------------------------------------------------------------------------------
- Thousands of Dollars -
ASSETS
Utility Plant
Plant in Service $ 2,722,465 $ 2,681,133
Utility Plant under Capital Leases 747,533 747,533
Construction Work in Progress 81,416 82,210
- ---------------------------------------------------------------------------------------------------------------------
Total Utility Plant 3,551,414 3,510,876
Less Accumulated Depreciation and Amortization (1,297,726) (1,257,585)
Less Accumulated Amortization of Capital Lease Assets (435,665) (421,135)
- ---------------------------------------------------------------------------------------------------------------------
Total Utility Plant - Net 1,818,023 1,832,156
- ---------------------------------------------------------------------------------------------------------------------
Investments and Other Property
Investments in Lease Debt and Equity 174,770 178,789
Other 24,135 41,285
- ---------------------------------------------------------------------------------------------------------------------
Total Investments and Other Property 198,905 220,074
- ---------------------------------------------------------------------------------------------------------------------
Note Receivable from UniSource Energy 74,772 70,132
- ---------------------------------------------------------------------------------------------------------------------
Current Assets
Cash and Cash Equivalents 81,434 65,262
Trade Accounts Receivable 82,055 70,415
Unbilled Accounts Receivable 40,874 31,104
Allowance for Doubtful Accounts (13,976) (11,034)
Intercompany Accounts Receivable 7,859 10,938
Materials and Fuel Inventory 48,638 50,107
Current Regulatory Assets 9,503 8,969
Deferred Income Taxes - Current 16,457 18,847
Interest Receivable - Current 11,326 11,561
Other 12,189 8,444
- ---------------------------------------------------------------------------------------------------------------------
Total Current Assets 296,359 264,613
- ---------------------------------------------------------------------------------------------------------------------
Regulatory and Other Assets
Transition Recovery Asset 253,582 274,182
Income Taxes Recoverable Through Future Revenues 47,236 49,849
Other Regulatory Assets 12,726 11,973
Other Assets 51,176 43,651
- ---------------------------------------------------------------------------------------------------------------------
Total Regulatory and Other Assets 364,720 379,655
- ---------------------------------------------------------------------------------------------------------------------
Total Assets $ 2,752,779 $ 2,766,630
=====================================================================================================================
CAPITALIZATION AND OTHER LIABILITIES
Capitalization
Common Stock Equity $ 421,551 $ 406,054
Capital Lease Obligations 724,579 762,323
Long-Term Debt 1,125,095 1,126,320
- ---------------------------------------------------------------------------------------------------------------------
Total Capitalization 2,271,225 2,294,697
- ---------------------------------------------------------------------------------------------------------------------
Current Liabilities
Current Obligations under Capital Leases 54,530 50,126
Current Maturities of Long-Term Debt 1,725 1,725
Accounts Payable 42,422 37,998
Intercompany Accounts Payable 8,533 8,413
Interest Accrued 46,379 58,620
Taxes Accrued 44,172 38,024
Accrued Employee Expenses 12,349 14,716
Other 9,467 8,063
- ---------------------------------------------------------------------------------------------------------------------
Total Current Liabilities 219,577 217,685
- ---------------------------------------------------------------------------------------------------------------------
Deferred Credits and Other Liabilities
Deferred Income Taxes - Noncurrent 128,037 128,336
Regulatory Liability - Net Cost of Removal for Interim Retirements 63,866 60,417
Other 70,074 65,495
- ---------------------------------------------------------------------------------------------------------------------
Total Deferred Credits and Other Liabilities 261,977 254,248
- ---------------------------------------------------------------------------------------------------------------------
Commitments and Contingencies (Note 9)
- ---------------------------------------------------------------------------------------------------------------------
Total Capitalization and Other Liabilities $ 2,752,779 $ 2,766,630
=====================================================================================================================
<fn>
See Notes to Condensed Consolidated Financial Statements.
</fn>
</table>
8
<table>
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, 2003 Restated
See Note 1 $ 655,534 $ (6,357) $ (241,279) $ (1,844) $ 406,054
- ----------------------------------------------------------------------------------------------------------------------------------
Comprehensive Income:
2004 Year-to-Date Net Income - - 18,811 - 18,811
Unrealized Gain on Cash Flow Hedges
(net of $961,000 income tax expense) - - - 1,466 1,466
Reclassification of Realized Gain on
Cash Flow Hedges to Net Income
(net of $133,000 income tax expense) - - - (203) (203)
-----------
Total Comprehensive Income 20,074
-----------
Dividend Paid - - (7,000) - (7,000)
Capital Contribution from UniSource Energy 2,423 - - - 2,423
- ----------------------------------------------------------------------------------------------------------------------------------
Balances at June 30, 2004 $ 657,957 $ (6,357) $ (229,468) $ (581) $ 421,551
==================================================================================================================================
<fn>
See Notes to Condensed Consolidated Financial Statements.
</fn>
</table>
9
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. 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 99.9% 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
85% of UniSource Energy's assets as of June 30, 2004. TEP generates, transmits
and distributes electricity. TEP serves approximately 370,000 retail electric
customers in a 1,155 square mile area in Pima and Cochise counties in Southern
Arizona. TEP also sells electricity to other utilities and power marketing
entities primarily located in the western U.S.
UES has no significant operations of its own, but owns all of the
common stock of UNS Gas, Inc. (UNS Gas) and UNS Electric, Inc. (UNS Electric).
On August 11, 2003, UniSource Energy completed the purchase of the Arizona gas
and electric system assets from Citizens Communications Company (Citizens) and
established two new operating companies, UNS Gas and UNS Electric, to acquire
these assets, as well as an intermediate holding company, UES, to hold the
common stock of UNS Gas and UNS Electric. The operating results of UNS Gas, UNS
Electric, and UES have been included in UniSource Energy's consolidated
financial statements since the acquisition date. UNS Electric procures,
transmits and distributes electricity to approximately 82,000 retail electric
customers in the Mohave county of Northern Arizona and the Santa Cruz county of
Southern Arizona. UNS Gas procures, transports and distributes natural gas to
approximately 129,000 customers in Mohave, Yavapai, Coconino, and Navajo
counties in Northern Arizona and Santa Cruz county in Southern Arizona.
Millennium's unregulated businesses are described in Note 8 and UED's
services are described in Note 7.
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 2003 Annual Report on Form 10-K.
Weather, among other factors, causes seasonal fluctuations in TEP and
UES' 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.
CHANGE IN UNBILLED REVENUE ESTIMATION METHODOLOGY AT TEP
TEP's and UES' 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 actual MWhs/therms delivered to the MWhs/therms
billed to TEP and UES retail customers. The excess of MWhs/therms delivered over
MWhs/therms billed is then allocated to the retail customer classes based on
estimated usage by each customer class. TEP and UES 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 UES gas sales increases during
the fall and winter months and decreases during the spring and summer months,
whereas, the unbilled revenue amount for UES electric sales increases during the
spring and summer months and decreases during the fall and winter months.
10
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
During the second quarter of 2004, we determined that the kWh
information used to estimate kWhs delivered to customers was generally
understated. Additionally, we determined that TEP's then existing method of
pricing computed unbilled kWh sales quantities among customer classes was
weighting usage by lower-priced customers too heavily and weighting usage by
higher-priced customers too lightly. For TEP, the price paid by customers varies
from a low of 3.7 cents per kWh for interruptible industrial load to a high of
13 cents per kWh for small commercial customers, so that allocations among
customer classes are a significant element of unbilled revenues. Effective with
the second quarter of 2004, we changed the estimation methodology used to
quantify unbilled kWh sales and price the computed unbilled kWh sales quantities
to more accurately reflect actual usage and restated prior periods.
Under the revised estimation methodology, unbilled sales are estimated
for the month by reviewing the meter reading schedule and determining the number
of billed and unbilled kWhs for each cycle. Current month unbilled kWhs are
allocated by customer class. New unbilled revenue amounts are recorded and
unbilled revenue estimates from the prior month are reversed. The primary
difference between the prior estimation methodology and the current methodology
results from the reversal of the prior month's accrued unbilled revenue rather
than a methodology that had the effect of reversing unbilled kWhs, and a more
precise application of the current rates by customer class to kWhs unbilled at
the end of each month.
The Condensed Consolidated Statements of Income for the three months
ended and the six months ended June 30, 2003 of UniSource Energy and TEP have
been restated to correct the understated revenues. The change in methodology and
correction of understated revenues resulted in the following revisions to the
consolidated financial statements:
<table>
Consolidated Statements of Income
UniSource Energy TEP
---------------------------- -------------------------
As As
Previously As Previously As
Three Months Ended June 30, 2003 Reported Restated Reported Restated
- ---------------------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
Electric Retail Sales $ 173,238 $177,237 $173,238 $177,237
Operating Revenues 211,341 216,073 209,956 214,688
Amortization of Transition Recovery Asset 7,762 7,892 7,762 7,892
Total Operating Expenses 169,129 169,092 158,903 158,863
Operating Income 42,212 46,981 51,053 55,825
Income Before Income Taxes 8,841 12,710 19,669 23,538
Income Taxes 4,258 5,790 8,495 10,027
Net Income $ 4,583 $6,920 $11,174 $13,511
- ---------------------------------------------------------------------------------------------------------------------------------
Basic EPS:
- ----------
Net Income $0.14 $0.20
Diluted EPS:
- -----------
Net Income $0.13 $0.20
</table>
11
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
<table>
Consolidated Statements of Income
UniSource Energy TEP
------------------------ ------------------------
As As
Previously As Previously As
Six Months Ended June 30, 2003 Reported Restated Reported Restated
- --------------------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
Electric Retail Sales $ 303,783 $306,372 $303,783 $306,372
Operating Revenues 384,507 388,320 382,503 386,315
Amortization of Transition Recovery Asset 11,370 11,619 11,370 11,619
Total Operating Expenses 329,162 329,270 310,744 310,849
Operating Income 55,345 59,050 71,759 75,466
Income (Loss) Before Income Taxes and Cumulative Effect of
Accounting Change (13,427) (11,087) 9,018 11,358
Income Taxes (3,809) (2,882) 5,020 5,947
Income (Loss) Before Cumulative Effect of Accounting Change (9,618) (8,205) 3,998 5,411
- -------------------------------------------------------------------------------------------------------------------------------
Net Income $ 57,853 $ 59,266 $ 71,469 $ 72,882
Basic EPS:
- ----------
Income (Loss) Before Cumulative Effect of Accounting Change $(0.29) $(0.25)
Net Income $1.71 $1.75
Diluted EPS:
- -----------
Income (Loss) Before Cumulative Effect of Accounting Change $(0.29) $(0.25)
Net Income $1.71 $1.75
</table>
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 13. We account 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.
Our stock options are granted with an exercise price equal to the
market value of the stock at the date of the grant. Accordingly, no compensation
expense is recorded for these awards. However, compensation expense is
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 Statement of Financial Accounting Standards No.
123, Accounting for Stock-Based Compensation (FAS 123), and recognized
compensation expense for all equity-based employee compensation awards:
12
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
UniSource Energy:
<table>
Three Months Ended June 30,
2004 2003 Restated
See Note 1
- ------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
(except per share data)
Net Income - As Reported $ 12,801 $ 6,920
Add: Equity-Based Compensation Expense
Included in Reported Net Income, Net of Related Tax Effects 66 320
Deduct: Total Equity-Based Employee Compensation Expense
Determined Under Fair Value Based Method for All Awards, Net
of Related Tax Effects (74) (568)
- ------------------------------------------------------------------------------------------------------------------
Pro Forma Net Income $ 12,793 $ 6,672
==================================================================================================================
Basic Earnings per Share:
As Reported $0.37 $0.20
Pro Forma $0.37 $0.20
==================================================================================================================
Diluted Earnings per Share:
As Reported $0.37 $0.20
Pro Forma $0.36 $0.19
==================================================================================================================
</table>
<table>
Six Months Ended June 30,
2004 2003 Restated
See Note 1
- ------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars-
(except per share data)
Net Income - As Reported $ 19,222 $ 59,266
Add: Equity-Based Compensation Expense
Included in Reported Net Income, Net of Related Tax Effects 1,309 426
Deduct: Total Equity-Based Employee Compensation Expense
Determined Under Fair Value Based Method for All Awards, Net
of Related Tax Effects (2,072) (912)
- ------------------------------------------------------------------------------------------------------------------
Pro Forma Net Income $ 18,459 $ 58,780
==================================================================================================================
Basic Earnings per Share:
As Reported $0.56 $1.75
Pro Forma $0.54 $1.74
==================================================================================================================
Diluted Earnings per Share:
As Reported $0.55 $1.75
Pro Forma $0.53 $1.74
==================================================================================================================
</table>
<table>
TEP:
Three Months Ended June 30,
2004 2003 Restated
See Note 1
- ------------------------------------------------------------------- -- ------------------- -- -------------------
-Thousands of Dollars-
Net Income - As Reported $ 18,017 $ 13,511
Add: Equity-Based Compensation Expense
Included in Reported Net Income, Net of Related Tax Effects 57 316
Deduct: Total Equity-Based Employee Compensation Expense
Determined Under Fair Value Based Method for All Awards, Net
of Related Tax Effects (64) (560)
- ------------------------------------------------------------------- -- ------------------- -- -------------------
Pro Forma Net Income $ 18,010 $ 13,267
=================================================================== == =================== == ===================
13
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Six Months Ended June 30,
2004 2003 Restated
See Note 1
- ------------------------------------------------------------------- -- ------------------- -- -------------------
-Thousands of Dollars-
Net Income - As Reported $ 18,811 $ 72,882
Add: Equity-Based Compensation Expense
Included in Reported Net Income, Net of Related Tax Effects 1,176 417
Deduct: Total Equity-Based Employee Compensation Expense
Determined Under Fair Value Based Method for All Awards, Net
of Related Tax Effects (1,925) (896)
- ------------------------------------------------------------------- -- ------------------- -- -------------------
Pro Forma Net Income $ 18,062 $ 72,403
=================================================================== == =================== == ===================
</table>
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 during the six months ended June 30, 2004. For the options granted
under the Omnibus Plan and Directors' Plan during the six months ended June 30,
2003, the following weighted average assumptions were used:
<table>
2003
- ------------------------------------------------------------------- -- ------------------- -- -------------------
Expected Life (Years) 5
Interest Rate 2.78%
Volatility 23.38%
Dividend Yield 3.44%
Weighted-Average Grant-Date Fair Value of Options Granted During
The Period $2.92
- ------------------------------------------------------------------- -- ------------------- -- -------------------
</table>
NOTE 2. PROPOSED ACQUISITION OF UNISOURCE ENERGY
- -------------------------------------------------
At a special meeting on March 29, 2004, UniSource Energy's shareholders
voted to approve an acquisition agreement UniSource Energy entered into on
November 21, 2003 with Saguaro Acquisition Corp., a wholly-owned indirect
subsidiary of Saguaro Utility Group L.P. (Saguaro Utility), providing for the
acquisition of all of the common stock of UniSource Energy for $25.25 per share
by an affiliate of Saguaro Utility. The acquisition agreement provides that
Saguaro Acquisition Corp. will merge with and into UniSource Energy, with
UniSource Energy surviving the merger as a wholly-owned indirect subsidiary of
Saguaro Utility. Upon consummation of the acquisition, Saguaro Utility will
cause the surviving corporation to pay approximately $880 million in cash to
UniSource Energy's shareholders and holders of stock options, stock units,
restricted stock and performance shares awarded under our stock based
compensation plans. In connection with the closing of the acquisition, Saguaro
Utility intends to cause the surviving corporation (i) to repay the $95 million
inter-company loan to UniSource Energy from TEP and (ii) to contribute up to
$168 million of equity into TEP. TEP will use a significant portion of these
proceeds to retire some of its outstanding debt. UniSource Energy expects the
acquisition, which is subject to several conditions including receipt of certain
regulatory approvals, to occur in the fourth quarter of 2004.
The acquisition agreement contains operating covenants with respect to
the operations of UniSource Energy's business pending the consummation of the
acquisition. Generally, unless UniSource Energy obtains Saguaro Acquisition
Corp.'s prior written consent, UniSource Energy must conduct business in the
ordinary course consistent with past practice and use all commercially
reasonable efforts to preserve substantially intact the present business
organization and present regulatory, business and employee relationships. In
addition, the acquisition agreement restricts certain activities, subject to the
receipt of Saguaro Acquisition Corp.'s prior written consent, including the
issuance or repurchase of capital stock, the amendment of organizational
documents, acquisitions and dispositions of assets, capital expenditures,
incurrence of indebtedness, modification of employee compensation and benefits,
changes in accounting methods, discharge of liabilities, and matters relating to
UniSource Energy's investment in Millennium.
Either UniSource Energy or Saguaro Acquisition Corp. may terminate the
acquisition agreement in certain circumstances, including if the acquisition is
not consummated by March 31, 2005 or certain regulatory approvals are not
obtained. In certain circumstances, upon the termination of the acquisition
agreement, UniSource Energy
14
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
would be required to pay Saguaro Acquisition Corp.'s expenses related to the
acquisition agreement and a termination fee in an aggregate amount of up to $25
million.
An affiliate of Saguaro Utility entered into a $410 million credit
agreement on March 25, 2004 that will be funded upon closing of the acquisition
of UniSource Energy. The credit agreement includes a $50 million revolving
credit facility for general corporate purposes and a $360 million term loan to
be used to fund a portion of the acquisition. The lenders' obligation to make
such loans are subject to various customary closing conditions.
The March 29, 2004 shareholder vote to approve the proposed merger
triggered vesting of all outstanding stock options under the Omnibus Plan, but
no additional compensation expense resulted from such vesting. See Note 13 for a
description of additional compensation expense recorded for the performance
shares due to accelerated vesting of the awards as a result of the March 29,
2004 shareholder vote.
NOTE 3. REGULATORY MATTERS
- ---------------------------
REGULATORY ACCOUNTING
TEP and UES 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 and UES' retail rates, the Arizona
Corporation Commission (ACC) may not allow TEP or UES 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 and UES are allowed to charge their customers. TEP and UES 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 regulatory assets, net of regulatory liabilities, totaled $259
million at June 30, 2004. Regulatory assets of $22 million are not presently
included in rate base and consequently are not earning a return on investment.
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 June 30, 2004, if
TEP had stopped applying FAS 71 to its remaining regulated operations, it would
have recorded an extraordinary after-tax loss of $157 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.
15
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
UES
UES' regulatory liabilities, net of regulatory assets, totaled $5
million at June 30, 2004. If UES stopped applying FAS 71 to its 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 liability balances, net of regulatory assets, at June
30, 2004, if UES had stopped applying FAS 71 to its regulated operations, it
would have recorded an extraordinary after-tax gain of $3 million. UES' 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.
RECENT REGULATORY ACTION FOR TEP
The TEP Settlement Agreement provided for certain retail rate
reductions from 1998 through 2000. In addition, TEP was required to file with
the ACC by June 1, 2004 general rate case information, including an updated cost
of service study. Under the terms of the TEP Settlement Agreement, no rate case
filed by TEP through 2008, including the filing on June 1, 2004, may result in a
rate increase. Any rate decrease resulting from the 2004 filing would be
effective no earlier than June 1, 2005.
On June 1, 2004, TEP filed general rate case information with the ACC.
TEP's filing does not propose any change in retail rates. Absent the restriction
on raising rates provided in the TEP Settlement Agreement, the data presented by
TEP would justify a request by TEP for 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 $115 million. The proposed weighted cost of
capital for the test year ended December 31, 2003 is 8.78%, including an 11.5%
return on equity.
TEP has requested a procedural conference with the ACC to discuss how
the review of the general rate case information will proceed.
NOTE 4. TEP CREDIT FACILITY AND DEBT REDEMPTION
- ------------------------------------------------
CREDIT FACILITY
On March 25, 2004, TEP entered into a new $401 million credit
agreement. The agreement replaces the credit facilities provided under TEP's
$401 million credit agreement that would have expired in 2006. The new credit
agreement includes a $60 million revolving credit facility for general corporate
purposes and a $341 million letter of credit facility, to support $329 million
aggregate principal amount of tax-exempt variable rate bonds. The credit
agreement has a five year term through June 30, 2009 and is secured by $401
million in aggregate principal amount of Second Mortgage Bonds issued under
TEP's General Second Mortgage Indenture.
The credit agreement contains a number of restrictive covenants,
including restrictions on additional indebtedness, liens, sale of assets and
sale-leasebacks. The credit agreement also contains several financial covenants
including: (a) minimum consolidated tangible net worth, (b) a minimum cash
coverage ratio, and (c) a maximum leverage ratio. Under the terms of the credit
agreement, TEP may pay dividends so long as it maintains compliance with the
credit agreement. The previous credit agreement had provided that dividends
could not exceed 65% of TEP's net income. The elimination of such covenant is
expected to satisfy, in part, one of the closing conditions contained in the
acquisition agreement that UniSource Energy entered into with Saguaro
Acquisition Corp. by permitting TEP to dividend all of its net income to its
shareholders. The credit agreement also provides that under certain
circumstances, certain regulatory actions could result in a required reduction
of the commitments. As of June 30, 2004, TEP was in compliance with the terms of
the Credit Agreement.
The letter of credit fee of 2.35% on the new facility is significantly
lower than the previous credit agreement's weighted average letter of credit fee
of approximately 5%. The agreement also provides for letter of credit fronting
fees of 0.25%, which will reduce to 0.125% upon the closing of Saguaro
Acquisition Corp.'s acquisition of UniSource Energy; the previous agreement's
fronting fee was 0.25%. Interest savings in 2004 will be partially offset by the
write-off of fees associated with the prior facility that were capitalized and
being amortized through 2006 and the amortization of fees associated with the
entry of the new facility. TEP wrote-off $2 million in fees associated with the
prior facility in March 2004, included in Long-Term Debt Interest Expense in
UniSource Energy and TEP's income statements.
16
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
At June 30, 2004, TEP had no outstanding borrowings under the revolving
credit facility. If TEP borrows under the revolving credit facility, the
borrowing costs would be at a variable interest rate consisting of a spread over
LIBOR or an alternate base rate. The spread is based upon a pricing grid tied to
TEP's leverage. The per annum rate currently in effect on borrowings under TEP's
revolving credit facility, based on its leverage, is LIBOR plus 2.25%. If TEP's
leverage were to change, the spread over LIBOR could range from 1.50% to 2.25%.
Also, TEP pays a commitment fee of 0.50% on the unused portion of the revolving
credit facility.
DEBT REDEMPTION
In July 2004, TEP redeemed the remaining $27 million of its 8.5% First
Mortgage Bonds which were due in 2009. TEP paid a premium of $0.4 million
related to this redemption.
NOTE 5. ACCOUNTING CHANGE: ACCOUNTING FOR ASSET RETIREMENT OBLIGATIONS
- ------------------------------------------------------------------------
TEP has identified legal obligations to retire generation plant assets
specified in land leases for its jointly-owned Navajo and Four Corners
Generating Stations. TEP also has certain environmental obligations at the San
Juan Generating Station (San Juan). TEP has estimated that its share of these
obligations will be approximately $38 million at the date of retirement. As of
June 30, 2004 and December 31, 2003, TEP had accrued approximately $1 million
for the final decommissioning of its generating facilities. This amount has been
recorded as an accrued asset retirement obligation on UniSource Energy and TEP's
balance sheets.
TEP and UES have various transmission and distribution lines that
operate under land leases and rights of way that contain end dates and
restorative clauses. TEP and UES operate their transmission and distribution
systems as if they will be operated in perpetuity and would continue to be used
or sold without land remediation. A final retirement occurs when an entire
transmission or distribution line is permanently removed from service. Interim
retirements occur as components of the system are replaced. As a result, TEP and
UES are not recognizing the costs of final removal of the transmission and
distribution lines in their financial statements. As of June 30, 2004 and
December 31, 2003, TEP had accrued $64 million and $60 million and UES had
accrued $1 million for the net cost of removal for interim retirements from its
transmission, distribution and general plant. These amounts have been recorded
as a regulatory liability on UniSource Energy and TEP's balance sheets.
Millennium and UED have no asset retirement obligations.
Upon adoption of FAS 143 on January 1, 2003, TEP recorded an asset
retirement obligation of $38 million at its net present value of $1 million,
increased depreciable assets by $0.1 million for asset retirement costs,
reversed $113 million of costs previously accrued for final removal from
accumulated depreciation, reversed previously recorded deferred tax assets of
$44 million and recognized the cumulative effect of accounting change as a gain
of $112 million ($67 million net of tax).
NOTE 6. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND TRADING ACTIVITIES
- ---------------------------------------------------------------------
TEP, UES and MEG's derivative activities are discussed fully in
UniSource Energy and TEP's 2003 Annual Report on Form 10-K.
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 the first six months of 2004, 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 will expire during the
summer months of 2004 through 2006, 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.
17
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
TEP and MEG's derivative activities are reported as follows:
o TEP's net unrealized and realized gains and losses on forward sales
contracts are components of Electric Wholesale Sales;
o TEP's net unrealized and realized gains and losses on forward purchase
contracts are components of Purchased Power;
o TEP's net unrealized gains and losses on commodity price swaps are
included in Other Comprehensive Income, which is a component of Common
Stock Equity;
o TEP's net realized gains and losses on commodity price swaps are
reclassified out of Other Comprehensive Income into Fuel expense; and
o MEG's net unrealized and realized gains and losses on trading
activities are components of 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 unrealized gains and losses from TEP's forward contracts
were less than $1 million for each of the three month periods ended June 30,
2004 and 2003 and less than $1 million for each of the six month periods ended
June 30, 2004 and 2003. The net pre-tax realized and unrealized gains and losses
from MEG's trading activities were also less than $1 million for each of the
three month periods ended June 30, 2004 and 2003 and less than $1 million for
each of the six month periods ended June 30, 2004 and 2003. The net pre-tax
unrealized gains and losses from TEP's commodity swap agreements recorded as
cash flow hedges and included in Other Comprehensive Income were $2 million as
of June 30, 2004. The net pre-tax realized gains and losses from TEP's commodity
swap agreements that were reclassified out of Other Comprehensive Income were
less than $1 million for each of the three and six months periods ended June 30,
2004. TEP had no material cash flow hedges at December 31, 2003.
TEP's derivative assets and liabilities are reported in Other Current
Assets and Other Current Liabilities on TEP and UniSource Energy's balance
sheets. The fair value of TEP's derivative assets was $2 million at June 30,
2004 and the fair value of TEP's derivative liabilities was less than $1 million
at December 31, 2003. MEG's trading assets and liabilities are reported in
Trading Assets and Trading Liabilities on UniSource Energy's balance sheet. The
fair value of MEG's trading assets, including its Emissions Allowance inventory,
was $63 million at June 30, 2004 and $22 million at December 31, 2003. The fair
value of MEG's trading liabilities was $60 million at June 30, 2004 and $19
million at December 31, 2003.
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 June 30, 2004, less than $1 million in sales were netted against
less than $1 million in purchases, resulting in a small net gain. For the six
months ended June 30, 2004, $2 million in sales were netted against $2 million
in purchases, resulting in a small net gain.
NOTE 7. BUSINESS SEGMENTS
- --------------------------
Based on the way we organize our operations and evaluate performance,
we have four reportable business segments:
(1) TEP, a vertically integrated electric utility business, is UniSource
Energy's largest subsidiary.
(2) UES is the holding company for UNS Gas, a regulated gas distribution
utility business, and UNS Electric, a regulated electric distribution
utility business. See Note 1.
(3) Millennium holds interests in unregulated energy and emerging
technology businesses. See Note 8.
(4) UED develops generating resources and performs other project
development activities, including facilitating the expansion of the
Springerville Generating Station.
Significant reconciling adjustments consist of the elimination of
intercompany activity and balances. Millennium recorded revenue from
transactions with TEP of $6 million and $5 million during the three-month
18
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
periods ended June 30, 2004 and June 30, 2003, and $8 million and $7 million
during the six-month periods ended June 30, 2004 and June 30, 2003. 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 the intercompany note between UniSource Energy and
TEP, as well as the related interest income and expense.
In June 2004, UED recognized an impairment loss on its note receivable
from an investee of Haddington Energy Partners II, LP (Haddington). As discussed
in Note 8, Haddington wrote off its investment in this investee during the
second quarter of 2004. As UED's recovery of the note receivable from the entity
is subordinated to the rights of others, UED wrote off the entire $2 million
balance due on the note at the time that Haddington determined that its
investment was impaired.
We record our percentage share of the earnings of affiliated companies,
except for investments where we provide all of the financing, in which case we
recognize 100% of the losses. See Note 8.
We disclose selected financial data for our business segments in the
following table:
<table>
Segments UniSource
----------------- ----------------- ---------------- Reconciling Energy
TEP UES Millennium UED Adjustments Consolidated
- ---------------------------------------------- -------------------------------------------------------------------------------------
- Millions of Dollars -
Income Statement
............................................. ............. ............ ............. ........... ............... ...............
Three months ended June 30, 2004:
............................................. ............. ............ ............. ........... ............... ...............
Operating Revenues - External $ 234 $ 56 $ - $ - $ - $ 290
............................................. ............. ............ ............. ........... ............... ...............
Operating Revenues - Intersegment - - 6 - (6) -
............................................. ............. ............ ............. ........... ............... ...............
Income (Loss) Before Income Taxes 33 1 (5) (2) (3) 24
............................................. ............. ............ ............. ........... ............... ...............
Net Income (Loss) 18 - (3) (1) (1) 13
............................................. ............. ............ ............. ........... ............... ...............
............................................. ............. ............ ............. ........... ............... ...............
Three months ended June 30, 2003 Restated, see
Note 1 :
.......................................... ............. ............ ............. ........... ............... ...............
Operating Revenues - External $ 215 $ - $ 1 $ - $ - $ 216
.......................................... ............. ............ ............. ........... ............... ..............
Operating Revenues - Intersegment - - 5 - (5) -
........................................... ............. ............ ............. ........... ............... ...............
Income (Loss) Before Income Taxes 24 - (7) - (4) 13
.............................................. ............. ............ ............. ........... ............... ..............
Net Income (Loss) 14 - (4) - (3) 7
.............................................. ............. ............ ............. ........... ............... ..............
............................................. ............. ............ ............. ........... ............... ...............
Six months ended June 30, 2004:
............................................. ............. ............ ............. ........... ............... ...............
Operating Revenues - External $ 420 $ 137 $ 3 $ - $ - $ 560
............................................. ............. ............ ............. ........... ............... ...............
Operating Revenues - Intersegment 1 - 8 - (9) -
................................................ ............. ............ ............. ........... ............... ............
Income (Loss) Before Income Taxes 36 9 (2) (2) (4) 37
................................................ ............. ............ ............. ........... ............... ............
Net Income (Loss) 19 5 (1) (1) (3) 19
............................................. ............. ............ ............. ........... ............... ..............
Six months ended June 30, 2003
Restated, see Note 1:
.............................................. ............. ............ ............. ........... ............... ..............
Operating Revenues - External $ 386 $ - $ 2 $ - $ - $ 388
.............................................. ............. ............ ............. ........... ............... ..............
Operating Revenues - Intersegment - - 7 - (7) -
.............................................. ............. ............ ............. ........... ............... ..............
Income (Loss) Before Income Taxes and 11 - (15) - (7) (11)
Cumulative Effect of Accounting Change
................................................ ............. ............ ............. ........... ............... ............
Net Income (Loss) 73 - (9) - (5) 59
------------------------------------------------ ------------- ------------ ------------- ----------- --------------- ------------
Balance Sheet
................................................ ............. ............ ............. ........... ............... ............
Total Assets, June 30, 2004 $2,753 $ 313 $ 226 $ 4 $(132) $3,164
................................................ ............. ............ ............. ........... ............... ............
Total Assets, December 31, 2003 Restated, see 2,767 309 181 3 (138) 3,122
Note 1
------------------------------------------------ ------------- ------------ ------------- ----------- --------------- ------------
</table>
19
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
NOTE 8. MILLENNIUM
- -------------------
See Note 7 for selected financial data of Millennium.
Through affiliates, Millennium holds investments in unregulated energy
and emerging technology companies. Millennium's assets represent 5% of UniSource
Energy's total assets at June 30, 2004 and 4% at December 31, 2003. Under the
acquisition agreement described in Note 2, UniSource Energy is limited as to the
amount it can invest in Millennium in the future. Consequently, Millennium's
ability to provide future funding for the operations of emerging companies could
be affected.
Millennium accounts for these investments under the consolidation and
equity methods. In some cases, Millennium is an investment's sole funder. 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 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.
A brief summary of Millennium's investments follows:
GLOBAL SOLAR ENERGY, INC. (Global Solar) primarily develops and
manufactures light weight thin-film photovoltaic cells and panels. Global
Solar's target markets have included military, space and commercial
applications. Millennium owns 99% of Global Solar. Millennium 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. During the first six months of
2004, Millennium made no contributions to Global Solar. However, UniSource
Energy provided $4 million to Global Solar under a tax sharing agreement.
Millennium has no remaining funding commitments to Global Solar, other than the
tax sharing agreement with UniSource Energy.
INFINITE POWER SOLUTIONS, INC. (IPS) develops thin-film lithium ion
batteries. Millennium owns 72% of IPS and accounts for it under the
consolidation method. IPS recognizes expense when funding is used for research,
development and administrative costs. Millennium's debt commitment to IPS was
$0.5 million at December 31, 2003, which Millennium funded during the first
quarter of 2004. Dow Corning Enterprises, Inc. (DCEI) made no additional
contributions to IPS during the same time period. In April 2004, Millennium and
DCEI committed to loan up to an additional $1 million each to IPS, and each
funded $0.5 million of the commitment at that time. DCEI funded its remaining
$0.5 million commitment during the second quarter of 2004, while Millennium
funded its remaining $0.5 million commitment in July 2004. Millennium has no
further funding commitments to IPS. Pursuant to the terms of the 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, we would recognize a
loss of approximately $4 million.
MICROSAT SYSTEMS, Inc. (MicroSat) develops small-scale satellites under
a U.S. government contract. In February 2004, pursuant to a settlement
agreement, the contract was terminated and MicroSat granted the government the
right to use the design data and transferred all hardware assets developed under
the contract to the government in exchange for the elimination of further
cost-sharing obligations under the contract. These assets will be used under a
new contract between MicroSat and the government, and may be used by the
government for other satellite development contracts not involving MicroSat.
However, MicroSat retains the right to use the design data on other government
and commercial contracts. MicroSat had previously deferred $2 million, before
tax, of revenues earned under the original contract. These revenues have now
been recognized, and Millennium recorded the income in the first quarter of
2004. Millennium owns 35% of MicroSat and, as sole funder, recognizes 100% of
MicroSat's net losses. Millennium made no contributions to MicroSat during the
first six months of 2004 and has no further funding commitments to MicroSat.
MEG is a wholly-owned subsidiary of Millennium, which manages and
trades emissions allowances, coal,
20
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
and related financial instruments. MEG's activities are described in Note 6.
HADDINGTON ENERGY PARTNERS II, LP (Haddington) funds energy-related
investments. A member of the UniSource Energy Board of Directors has an
investment in Haddington and is a managing director of the general partner of
the limited partnership. Millennium committed $15 million in capital, excluding
fees, to Haddington in exchange for approximately 31% ownership. At June 30,
2004, Millennium had funded $9 million of this commitment, $0.2 million of which
was funded during the first six months of 2004. Millennium expects the balance
to be funded over the next three years. In March 2004, Haddington sold one of
its investments and recognized the related gain as income. In April 2004,
Millennium received a $7 million distribution from Haddington related to the
sale. In June 2004, Haddington wrote off another of its investments and
recognized the related loss. Millennium's share of the loss was $2 million,
before tax. Millennium recorded its share of Haddington's income and loss during
the first six months of 2004, which includes Haddington's gains and losses on
investments. Millennium accounts for its investment in Haddington under the
equity method.
VALLEY VENTURES III, LP (Valley Ventures) is a venture capital fund
that invests in information technology, microelectronics and biotechnology,
primarily within the southwestern U.S. Another member of the UniSource Energy
Board of Directors is a general partner of the company that manages the fund.
Millennium committed $6 million, including fees, to the fund and owns
approximately 15% of the fund. As of June 30, 2004, Millennium had funded $2
million of this commitment, $0.6 million of which was funded during the first
six months of 2004. Millennium expects the balance to be funded by the end of
2007. Millennium accounts for this investment under the equity method due to an
ability to exercise significant influence over the fund based on the related
party affiliation disclosed above.
CARBOELECTRICA SABINAS, S.DE R.L. DE C.V. (Sabinas) is a Mexican
limited liability company created to develop up to 800 megawatts (MW) of
coal-fired generation in the Sabinas region of Coahuila, Mexico. Sabinas also
owns 19.5% of Minerales de Monclova, S.A. de C.V. (Mimosa). Mimosa is an owner
of coal and associated gas reserves. Mimosa supplies metallurgical coal to the
Mexican steel industry and thermal coal to the major electric utility in Mexico.
Millennium owns 50% of Sabinas. Altos Hornos de Mexico, S.A. de C.V. (AHMSA) and
affiliates own the remaining 50%. UniSource Energy's Chairman, President and
Chief Executive Officer is an alternate member of the board of directors of
AHMSA. Since 1999, both AHMSA and Mimosa are parties to a suspension of payments
procedure, under applicable Mexican law, which is the equivalent of a U.S.
Chapter 11 proceeding. Under certain circumstances, Millennium has the right to
sell (a put option) its interest in Sabinas to an AHMSA affiliate for $20
million plus an accrued service fee. These circumstances include failure of
Sabinas to reach financial closing on the generation project within a specified
time. Millennium's put option is secured by collateral initially valued in
excess of $20 million. Millennium accounts for the investment in Sabinas under
the equity method; however, Sabinas accounts for its investment in Mimosa under
the cost method.
NATIONS ENERGY CORPORATION (Nations Energy) is wholly owned by
Millennium. Through subsidiaries, Nations Energy has a 32% interest in a 43 MW
power plant in Panama. Although Nations Energy still intends to sell its
interest in this plant, the $0.8 million book value of the investment was
written off in June 2004 because attempts to sell the asset to date have been
unsuccessful.
NATIONS ENERGY CONTINGENCY
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 receivable from
Mirant Curacao. The receivable 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 receivable. As of June 30, 2004, Nations
Energy's receivable from Mirant Curacao was approximately $8 million. The
receivable 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 on June 30, 2004. The remaining payments are expected as
follows: $4 million in July 2005 and $5 million in July 2006.
The receivable 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 remaining receivable and any applicable interest.
However, Nations Energy cannot predict the ultimate outcome that Mirant's
bankruptcy will
21
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
have on the collectibility of the receivable from Mirant Curacao. Nations Energy
will continue to evaluate the collectibility of the receivable, but currently
expects to collect the receivable in its entirety and has not recorded any
reserve for this receivable.
MILLENNIUM COMMITMENTS
Millennium's funding levels and share ownership in its investments are
subject to change in the future. Millennium's outstanding equity commitments are
currently limited to $6 million to Haddington and $4 million to Valley Ventures.
Millennium has no remaining debt commitments after the $0.5 million payment to
IPS in July 2004. Millennium may commit to provide additional funding to its
investments in the future.
Global Solar had commitments totaling $1 million at June 30, 2004 and
December 31, 2003 to incur future expenses relating to government contracts.
NOTE 9. COMMITMENTS AND CONTINGENCIES
- --------------------------------------
MILLENNIUM COMMITMENTS AND CONTINGENCY
See Note 8 for a description of Millennium's commitments and
contingency.
UNISOURCE ENERGY CONTINGENCIES
Acquisition Fees
UniSource Energy has entered into agreements with New Harbor
Incorporated (New Harbor) and Morgan Stanley & Co. Incorporated (Morgan Stanley)
in connection with the acquisition of UniSource Energy by Saguaro Utility. The
transaction fee payable to New Harbor is $9 million. UniSource Energy paid New
Harbor $2 million upon announcement of the transaction in November 2003, with
the balance of the transaction fee contingent and payable upon the closing of
the transaction. UniSource Energy has agreed to pay Morgan Stanley a transaction
fee of up to $3 million, which includes their monthly advisory fee, in
connection with the acquisition. UniSource Energy paid Morgan Stanley $1 million
in November 2003 and $0.4 million in April 2004 upon shareholders approving the
transaction, and will pay Morgan Stanley $1 million contingent and payable upon
the acquisition closing. UniSource Energy expensed these transaction fees as
incurred which are included in Other Operations and Maintenance Expense on the
Statements of Income and in Payment of Other Operation and Maintenance Costs on
the Statements of Cash Flows.
In certain circumstances, in the event of termination of the
acquisition agreement, UniSource Energy would be required to pay Saguaro
Acquisition Corp.'s expenses and a termination fee in an aggregate amount of up
to $25 million.
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 Court granted TEP and the ACC's motion
for summary judgment from the environmental activist groups. The environmental
activist groups appealed the Superior Court decision on December 30, 2003 and
filed an amended notice of appeal on January 2, 2004.
In November 2001, the Grand Canyon Trust (GCT), an environmental
activist group, filed a complaint in U.S. District Court against TEP for alleged
violations of the Clean Air Act at the Springerville Generating Station. The
complaint alleged that more stringent emission standards should apply to Units 1
and 2. These standards would require new permits and the installation of
additional facilities, meeting Best Available Control Technology
22
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
standards, for the continued operation of Units 1 and 2. In 2002, the U.S.
District Court granted TEP's motion for summary judgment on one of the primary
issues in the case: whether TEP commenced construction within 18 months and/or
by March 19, 1979, after the original 1977 air permit covering Units 1 and 2 was
issued. The Court found that TEP had commenced construction of the Springerville
Generating Station in the time periods required by the original permits. There
were two remaining allegations: that (a) TEP discontinued construction for a
period of 18 months or longer and did not complete construction in a reasonable
period of time, and (b) TEP did not commence construction, for purposes of New
Source Performance Standard applicability, by September 18, 1978. On March 4,
2003, the U.S. District Court determined that the GCT had not commenced the case
on a timely basis and dismissed the case. The GCT has appealed this decision to
the U.S. Court of Appeals for the 9th Circuit. Oral argument on the matter was
heard by the 9th Circuit on April 15, 2004, and a decision is pending.
TEP believes these claims are without merit and intends to vigorously
contest them.
Litigation and Claims Related to San Juan Generating Station
On May 16, 2002, the GCT and the Sierra Club filed a citizen lawsuit
under the Clean Air Act in federal district court in New Mexico against Public
Service Company of New Mexico (PNM) as operator of San Juan. TEP owns 50% of San
Juan Units 1 and 2, which equates to 19.8% of the total San Juan Generating
Station. The lawsuit alleges two violations of the Clean Air Act and related
regulations and permits. One of the two claims, concerning the initial
permitting of San Juan, was dismissed by the court in August 2003. The remaining
claim alleged that PNM violated its present Title V operating permit for Units
1, 3 and 4 by exceeding the 20% opacity standard on numerous occasions between
1998 and 2002; opacity is a means to monitor the particulate matter contained in
an emission. PNM has exchanged written settlement offers and entered into a
settlement conference with the plaintiffs. The trial will continue in the third
quarter of 2004 if the parties are unable to reach settlement.
In September 2003, the New Mexico Environment Department (NMED)
notified PNM, operator of San Juan, of alleged excess emissions and opacity in
violation of the permits at San Juan Units 1, 3, and 4. The NMED issued a draft
compliance order assessing unspecified civil penalties. PNM has entered into
discussions with the NMED concerning the alleged excess emissions and opacity
violations. No compliance order has been issued in this matter.
The 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. PNM and the coal supplier to San Juan vigorously deny these
allegations. The EPA is investigating the claims.
Because settlement negotiations are ongoing, and the matter may proceed
to trial, TEP is unable to predict the outcome of this litigation and claims.
Postretirement and Pension Benefit Costs at Various Generating Stations
The coal suppliers to Springerville Generating Station and each of
TEP's remote generating stations have submitted demands for payment by TEP of
postretirement and pension benefit costs for these coal suppliers' employees
under the coal supply agreements with TEP.
Navajo Generating Station: Peabody Western Coal Company (Peabody), the
coal supplier to the Navajo Generating Station, has filed a lawsuit against the
participants at Navajo, including TEP, for retiree postretirement benefit costs.
TEP owns 7.5% of the Navajo Generating Station. In December 2003, the Navajo
participants and Peabody agreed to stay the discovery process in this litigation
until August 31, 2004 to give the parties time to explore a possible settlement.
To the extent that amounts become known and payment probable, TEP will
record a liability for additional postretirement and pension benefit costs at
the Navajo and San Juan Generating Stations. TEP does not expect any settlement
to be material to TEP.
Springerville Generating Station: In June 2004, TEP paid $3 million in
settlement of the claim for postretirement benefit costs related to the coal
supply agreement at Springerville Generating Station. In addition, a clause was
deleted from the coal supply agreement that would have allowed costs related to
increases in welfare
23
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
and pension benefits resulting from attempts to unionize or union negotiations
to be passed to TEP. TEP expensed $0.5 million in 2003 and $0.5 million in June
2004 as the cost associated with the settlement for the period April 2002
through June 2004. The remaining settlement of $2 million represents a
prepayment and will be amortized to coal inventory over the remaining life of
the coal supply agreement through 2010 and expensed as fuel is burned.
Four Corners Generating Station: The claim for postretirement at Four
Corners was settled as part of the coal contract extension. TEP paid $0.3
million for postretirement benefits in settlement in September 2003.
Environmental Reclamation at Remote Generating Stations
TEP pays on-going reclamation costs at each of its remote generating
stations, and it is probable that TEP will have to pay a portion of final
reclamation costs at the coal mines which supply the remote generating stations.
San Juan Generating Station: In June 2003, TEP received an estimate of
the reclamation liability at the coal mine that supplies San Juan in which
post-term reclamation activities are assumed to occur over a 16-year period
beginning in 2028. The expected aggregate undiscounted reclamation liability
totals $122 million of which TEP's portion of the liability, based on its
ownership of San Juan, totals $24 million. The present value of TEP's liability
for post-term reclamation at a 10% credit-adjusted risk free rate approximates
$7 million at December 31, 2017, the expiration date of the coal supply
agreement, and will be recognized over the remaining term of the coal supply
agreement. At June 30, 2004, TEP has recorded $0.5 million of its post-term
reclamation liability at San Juan. Amounts recorded for post-term 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 post-term
reclamation obligation at San Juan will be material to TEP in any single year
since recognition occurs over the remaining 14 year life of its coal supply
agreement.
Other Remote Generating Stations: Although a cost is probable at TEP's
other remote generating stations, it is not possible at this time to reasonably
estimate the amount of any obligation for final reclamation because remediation
alternatives have not yet advanced to the stage where a reasonable estimate of
any cost can be made. As amounts become known, TEP will recognize a liability
for final reclamation over the remaining lives of its coal supply agreements.
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
1) 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 system assets, 2) UniSource Energy's guarantee of
approximately $24 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 3) Millennium's guarantee of approximately $3
million in commodity-related payments for MEG at June 30, 2004. To the extent
liabilities exist under the contracts subject to these guarantees, such
liabilities are included in UniSource Energy's 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 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.
24
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
NOTE 10. 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 June 30,
2004 and $26 million at December 31, 2003, net of allowances. TEP's Allowance
for Doubtful Accounts on the balance sheet includes $13 million at June 30, 2004
and $10 million at December 31, 2003 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 June 30, 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 in the second quarter of 2004 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. TEP 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 11. UNISOURCE ENERGY EARNINGS PER SHARE (EPS)
- ---------------------------------------------------
Basic EPS is computed by dividing net income by the weighted average
number of common shares outstanding during the period. Diluted EPS assumes that
proceeds from the hypothetical exercise of stock options and other equity-based
awards are used to repurchase outstanding shares of stock at the average fair
market price during the reporting period. The numerator in calculating both
basic and diluted earnings per share for each period is net income. The
following table shows the effects of potential dilutive common stock on the
weighted average number of shares:
<table>
Three Months Ended Six Months Ended
June 30, June 30,
2004 2003 2004 2003
- ----------------------------------------------------------------------- ------------------------- ----------------------
- In Thousands -
Denominator:
Average Shares of Common Stock Outstanding 34,392 33,821 34,288 33,780
Effect of Dilutive Securities:
Options and Stock Issuable under Employee Benefit Plans 663 455 683 -
- ----------------------------------------------------------------------- ------------------------- ----------------------
Total Shares 35,055 34,276 34,971 33,780
======================================================================= ========================= ======================
</table>
There were no antidilutive options outstanding during the three month
and six month periods ended June 30, 2004. Options to purchase 42,000 shares of
common stock at $18.74 to $18.84 per share were outstanding during the three
months ended June 30, 2003 but were not included in the computation of diluted
EPS because the options' exercise price was greater than the average market
price of the common stock and, therefore, the effect would be antidilutive.
Similarly, an average of 537,000 antidilutive options was excluded from the year
to date computation of diluted EPS for the six months ended June 30, 2003.
Additionally, the dilutive share base for the six months ended June 30,
2003 excludes 414,000 average incremental common shares related to options and
contingently issuable shares that are excluded due to their antidilutive effect
as a result of UniSource Energy's loss before cumulative effect of accounting
change for that six month period.
25
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
NOTE 12. 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 IRS
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. Concurrent with the
acquisition of the Arizona gas and electric assets from Citizens on August 11,
2003, UES assumed a $2 million liability for 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 (FAS 106), over actual benefit payments.
FASB Staff Position No. FAS 106-2, Accounting and Disclosure
Requirements Related to the Medicare Prescription Drug, Improvement and
Modernization Act of 2003 (FSP 106-2), provides guidance related to accounting
for the federal subsidy available to employers providing retirees with
prescription drug benefits that are at least actuarially equivalent to Medicare
Part D. For public companies, FSP 106-2 is effective for the first interim or
annual period beginning after June 15, 2004. FAS 106 requires presently enacted
changes in relevant laws to be considered in current period measurements of
postretirement benefit costs and the Accumulated Projected Benefit Obligation.
The benefits provided to retirees of TEP do not include prescription drug
coverage after a retiree becomes eligible for Medicare. Prescription drug
benefits are available to a limited number of UniSource Energy retirees who are
Medicare eligible. However, the Accumulated Projected Benefit Obligation or net
periodic postretirement benefit cost do not reflect any amount associated with
the subsidy because at this time we are unable to determine whether this drug
coverage is comparable (actuarially equivalent) or more generous than Medicare
Part D. The effects of the Medicare Prescription Drug, Improvement, and
Modernization Act of 2003 will be incorporated in our next measurement of plan
assets and obligations. Adoption of FSP 106-2 is not expected to have a
significant impact on our postretirement benefit costs or cash flows.
COMPONENTS OF NET PERIODIC BENEFIT COST
The components of net periodic benefit costs are as follows:
<table>
Other Postretirement
Pension Benefits Benefits
----------------------------------------------------
Three Months Ended Three Months Ended
June 30, June 30,
2004 2003 2004 2003
- ---------------------------------------------------------------------------------------------------------
-Millions of Dollars -
Components of Net Periodic Benefit Cost
Service Cost $ 1.5 $ 1.2 $ 0.5 $ 0.4
Interest Cost 2.4 2.1 0.9 1.0
Expected Return on Plan Assets (2.7) (2.3) - -
Prior Service Cost Amortization 0.5 0.4 (0.4) (0.4)
Recognized Actuarial Loss 0.4 0.5 0.5 0.6
- ---------------------------------------------------------------------------------------------------------
Net Periodic Benefit Cost $ 2.1 $ 1.9 $ 1.5 $ 1.6
=========================================================================================================
</table>
<table>
26
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Other Postretirement
Pension Benefits Benefits
----------------------------------------------------
Six Months Ended Six Months Ended
June 30, June 30,
2004 2003 2004 2003
- ---------------------------------------------------------------------------------------------------------
-Millions of Dollars -
Components of Net Periodic Benefit Cost
Service Cost $ 3.0 $ 2.4 $ 1.0 $ 0.8
Interest Cost 4.8 4.2 1.8 2.0
Expected Return on Plan Assets (5.4) (4.6) - -
Prior Service Cost Amortization 1.0 0.8 (0.8) (0.8)
Recognized Actuarial Loss 0.8 1.0 1.0 1.2
- ---------------------------------------------------------------------------------------------------------
Net Periodic Benefit Cost $ 4.2 $ 3.8 $ 3.0 $ 3.2
=========================================================================================================
</table>
EMPLOYER CONTRIBUTIONS
We previously disclosed in our financial statements for the year ended
December 31, 2003 that TEP and UES' expected pension plan contributions in 2004
were $6 million and $0.5 million, respectively. As of June 30, 2004, TEP
anticipates making contributions of $5 million in 2004 of which $1 million have
been made. UES presently anticipates contributing $1 million in 2004, which was
substantially funded as of June 30, 2004.
NOTE 13. EQUITY-BASED COMPENSATION PLANS
- -----------------------------------------
We account for UniSource Energy's two equity-based compensation plans,
the Directors' Plan and the Omnibus Plan, under the recognition and measurement
principles of APB 25 and related interpretations. See Note 1.
The acquisition agreement discussed in Note 2 limits the amount of
capital stock that UniSource Energy can issue under its stock plans and requires
that both of UniSource Energy's stock plans must be terminated effective as of
the closing of the merger. Additionally, both plans contain "Change in Control"
provisions that provide for accelerated vesting of awards when certain
conditions are met. The March 29, 2004 shareholder vote to approve the proposed
merger triggered 100% vesting of all awards under the Omnibus Plan. The
provision in the Directors' Plan results in 100% vesting of all awards if and
when the merger is consummated.
At June 30, 2004, we had stock options, stock units and restricted
stock grants outstanding as discussed below.
STOCK OPTIONS
No stock options were granted under the Directors' Plan during the six
months ended June 30, 2004. A total of 1,196 stock options were granted under
this plan during the second quarter of 2003 and 22,418 stock options were
granted during the six-month period ended June 30, 2003. There were no stock
options granted to key employees under the Omnibus Plan during the six months
ended June 30, 2004. Key employees were awarded 97,818 stock options under this
plan during the three and six months ended June 30, 2003. 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.
27
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
A summary of the stock option activity of the Directors' Plan and
Omnibus Plan is as follows:
<table>
Six Months Ended June 30,
2004 2003
- --------------------------------------------------------------------------------------------------------
Weighted Weighted
Average Average
Exercise Exercise
Shares Price Shares Price
- --------------------------------------------------------------------------------------------------------
Options Outstanding,
Beginning of Period 2,478,551 $16.04 2,576,819 $15.77
Granted - - 120,236 $17.77
Exercised (360,166) $15.12 (14,349) $13.25
Forfeited (2,613) $13.86 (12,546) $14.29
----------------- ----------------
Options Outstanding,
End of Period 2,115,772 $16.20 2,670,160 $15.88
================= ================
Options Exercisable,
End of Period 2,092,169 $16.18 1,623,294 $14.93
Weighted Average Remaining Contractual Life at June 30, 2004: 6.17
- --------------------------------------------------------------------------------------------------------
</table>
As discussed in Note 1, we apply APB 25 in accounting for our stock
option plans. We have not recognized any compensation cost for these options
because our stock options are granted with an exercise price equal to the market
value of the stock at the grant date. We have also adopted the disclosure-only
provisions of FAS 123. We present, in Note 1, the effect on net income and
earnings per share as if the company had applied the fair value recognition
provisions of FAS 123, as required by Statement of Financial Accounting
Standards No. 148, Accounting for Stock-Based Compensation-Transition and
Disclosure.
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. We recognized compensation expense for dividend
equivalents on stock option grants of $0.1 million for each of the three month
periods ended June 30, 2004 and 2003, and $0.2 million for each of the six month
periods ended June 30, 2004 and 2003.
RESTRICTED STOCK AND STOCK UNITS
There were no new restricted stock awards granted to directors in the
second quarter of 2004 or 2003. In the first quarter of 2004 and 2003, we
granted restricted stock awards to directors totaling 6,480 shares and 5,157
shares, respectively. The grant date fair value of the shares was $24.68 per
share in 2004 and $17.44 per share in 2003. Directors may elect to receive stock
units in lieu of restricted shares. As discussed above, Directors' awards were
not affected by the shareholder vote to approve the proposed merger. The
restricted shares or stock units become 100% vested on the third anniversary of
the grant date, or on consummation of the merger. Compensation expense equal to
the fair market value on the date of the award is recognized over the vesting
period. We recorded compensation expense related to these awards of less than
$0.1 million for each of the three and six month periods ended June 30, 2004 and
2003.
There were no new stock unit awards granted under the Omnibus Plan in
the six month periods ended June 30, 2004 or 2003. 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 and were not impacted by
the shareholder vote to approve the proposed merger. As all awards had vested,
we did not recognize any compensation expense related to stock unit awards
during the second quarter of 2004. We recognized compensation expense related to
earlier awards of less than $0.1 million for the three months ended June 30,
2003 and for each of the six month periods ended June 30, 2004 and 2003.
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
28
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
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. Compensation expense of $2 million was recorded in the first
quarter of 2004 for this award. We recognized compensation expense of $0.4
million related to performance shares for each of the three and six month
periods ended June 30, 2003.
NOTE 14. INCOME AND OTHER TAXES
- --------------------------------
INCOME TAXES
The differences between the income tax expense (benefit) and the amount
obtained by multiplying pre-tax income (loss) before cumulative effect of
accounting change by the U.S. statutory federal income tax rate of 35% are as
follows:
<table>
UniSource Energy
------------------------------------------------------------
Three Months Ended Six Months Ended
June 30, June 30,
2004 2003 Restated 2004 2003 Restated
See Note 1 See Note 1
- ------------------------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars -
Federal Income Tax Expense (Benefit) at Statutory Rate $ 8,560 $ 4,449 $ 12,875 $ (3,880)
State Income Tax Expense (Benefit), Net of Federal Deduction 1,125 584 1,692 (510)
Depreciation Differences (Flow Through Basis) 789 1,086 1,578 2,173
Tax Credits (129) (380) (258) (760)
Other 1,310 51 1,677 95
- ------------------------------------------------------------------------------------------------------------------------------------
Income Tax Expense (Benefit) 11,655 5,790 17,564 (2,882)
- ------------------------------------------------------------------------------------------------------------------------------------
Tax on Cumulative Effect of Accounting Change (see Note 5) - - - 44,236
- ------------------------------------------------------------------------------------------------------------------------------------
Total Federal and State Income Tax Expense $ 11,655 $ 5,790 $ 17,564 $ 41,354
====================================================================================================================================
</table>
<table>
TEP
------------------------------------------------------------
Three Months Ended Six Months Ended
June 30, June 30,
2004 2003 Restated 2004 2003 Restated
See Note 1 See Note 1
- ------------------------------------------------------------------------------------------------------------------------------------
-Thousands of Dollars -
Federal Income Tax Expense at Statutory Rate $ 11,500 $ 8,238 $ 12,504 $ 3,975
State Income Tax Expense, Net of Federal Deduction 1,511 1,083 1,643 522
Depreciation Differences (Flow Through Basis) 789 1,086 1,578 2,173
Tax Credits (129) (380) (258) (760)
Other 1,170 - 1,448 37
- ------------------------------------------------------------------------------------------------------------------------------------
Income Tax Expense 14,841 10,027 16,915 5,947
- ------------------------------------------------------------------------------------------------------------------------------------
Tax on Cumulative Effect of Accounting Change (see Note 5) - - - 44,236
- ------------------------------------------------------------------------------------------------------------------------------------
Total Federal and State Income Tax Expense $ 14,841 $ 10,027 $ 16,915 $ 50,183
====================================================================================================================================
</table>
The total Federal and State Income Tax Expense in the table above is
included on UniSource Energy and TEP's income statements.
29
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
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 electricity is delivered to
customers. Neither the amounts billed nor payable are reflected in the income
statement.
NOTE 15. NEW ACCOUNTING PRONOUNCEMENTS
- ---------------------------------------
The FASB recently issued the following Statements of Financial
Accounting Standards (FAS) and FASB Interpretations (FIN):
o FIN 46, Consolidation of Variable Interest Entities, was issued in
January 2003, and was subsequently revised in December 2003 (FIN 46R).
The primary objectives of FIN 46R are to provide guidance on the
identification of entities for which control is achieved through means
other than through voting rights (variable interest entities) and to
determine when and which business enterprises should consolidate the
variable interest entity (primary beneficiary). FIN 46R requires that
both the primary beneficiary and all other enterprises with a
significant variable interest make additional disclosures. For public
companies, the revised FIN 46R is effective for financial periods
ending after March 15, 2004. The adoption of FIN 46R did not have a
significant impact on our financial statements.
o FAS 132, Employers' Disclosures about Pensions and Other Postretirement
Benefits (revised 2003), was issued by the FASB in December 2003. FAS
132 requires additional disclosures about the assets, obligations, cash
flows, and net periodic benefit cost of defined benefit pension plans
and other defined benefit postretirement plans beyond those in the
original Statement 132 which it replaces. FAS 132, as revised, is
effective for fiscal years ending after December 15, 2003. The revised
disclosure requirements are included in Note 12 above.
See our discussion of FASB Staff Position No. FAS 106-2, Accounting and
Disclosure Requirements Related to the Medicare Prescription Drug, Improvement
and Modernization Act of 2003, in Note 12 above.
In August 2003, the Emerging Issues Task Force (EITF) published Issue
No. 03-11, Reporting Realized Gains and Losses on Derivative Instruments That
Are Subject to FASB Statement No. 133, Accounting for Derivative Instruments and
Hedging Activities, and Not "Held for Trading Purposes" as Defined in EITF Issue
No. 02-3 (EITF 03-11). EITF 03-11 discusses whether realized gains and losses
should be shown gross or net in the income statement for contracts that are not
held for trading purposes, as defined in EITF 02-3, but are derivatives subject
to FAS 133. Determining whether realized gains and losses on derivative
contracts not held for trading purposes should be reported in the income
statement on a gross or net basis is a matter of judgment that depends on the
relevant facts and circumstances with respect to the various activities of the
entity. Retroactive application of EITF 03-11 is not required. Beginning January
1, 2004, the realized gains and losses on derivative instruments that are not
held for trading purposes but are eventually net settled are shown net in the
income statement. The impact of adopting EITF 03-11 was immaterial as of June
30, 2004. See Note 6.
30
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
NOTE 16. SUPPLEMENTAL CASH FLOW INFORMATION
- --------------------------------------------
A reconciliation of net income to net cash flows from operating
activities follows:
<table>
UniSource Energy
--------------------------------
Six Months Ended
June 30,
2004 2003 Restated
See Note 1
- ---------------------------------------------------------------------------------------- ---------------- ---------------
-Thousands of Dollars-
Net Income $ 19,222 $ 59,266
Adjustments to Reconcile Net Income
To Net Cash Flows
Cumulative Effect of Accounting Change-Net of Tax - (67,471)
Depreciation and Amortization Expense 71,696 61,440
Depreciation Recorded to Fuel and Other O&M Expense 3,098 2,803
Amortization of Transition Recovery Asset 20,600 11,619
Net Unrealized Gain on TEP Forward Electric Sales (780) 109
Net Unrealized Loss on TEP Forward Electric Purchases 83 -
Net Unrealized Gain on MEG Trading Activities (1,689) (1,531)
Amortization of Deferred Debt-Related Costs included in Interest Expense 3,295 1,461
Provision for Bad Debts 1,734 3,608
Deferred Income Taxes 3,200 13,318
(Gains) Losses from Equity Method Entities (5,418) 1,950
Other 17,873 (1,655)
Changes in Assets and Liabilities which Provided (Used)
Cash Exclusive of Changes Shown Separately
Accounts Receivable (16,979) (11,398)
Materials and Fuel Inventory (255) (7,140)
Accounts Payable 6,459 2,368
Interest Accrued (2,182) (1,750)
Income Tax Receivable - (9,463)
Taxes Accrued 15,281 (12,014)
Other Current Assets (39,263) (10,702)
Other Current Liabilities 42,218 9,465
- ---------------------------------------------------------------------------------------- ---------------- ---------------
Net Cash Flows - Operating Activities $138,193 $ 44,283
======================================================================================== ================ ===============
</table>
31
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (CONCLUDED)
<table>
TEP
--------------------------------
Six Months Ended
June 30,
2004 2003 Restated
See Note 1
- ---------------------------------------------------------------------------------------- ---------------- ---------------
-Thousands of Dollars-
Net Income $ 18,811 $ 72,882
Adjustments to Reconcile Net Income
To Net Cash Flows
Cumulative Effect of Accounting Change-Net of Tax - (67,471)
Depreciation and Amortization Expense 62,438 59,384
Depreciation Recorded to Fuel and Other O&M Expense 3,098 2,803
Amortization of Transition Recovery Asset 20,600 11,619
Net Unrealized Gain on TEP Forward Electric Sales (780) 109
Net Unrealized Loss on TEP Forward Electric Purchases 83 -
Amortization of Deferred Debt-Related Costs included in Interest Expense 3,141 1,461
Provision for Bad Debts 813 3,608
Deferred Income Taxes 7,686 11,518
Gains from Equity Method Entities (62) (81)
Interest on Note Receivable from UniSource Energy (4,639) (5,079)
Other 21,278 1,435
Changes in Assets and Liabilities which Provided (Used)
Cash Exclusive of Changes Shown Separately
Accounts Receivable (23,162) (14,018)
Materials and Fuel Inventory 1,469 (6,098)
Accounts Payable 5,872 10,042
Interest Accrued (1,983) (1,750)
Income Taxes Receivable - (568)
Taxes Accrued 5,605 (14,024)
Other Current Assets (1,105) 2,086
Other Current Liabilities (3,212) (4,490)
- ---------------------------------------------------------------------------------------- ---------------- ---------------
Net Cash Flows - Operating Activities $115,951 $ 63,368
======================================================================================== ================ ===============
</table>
NOTE 17. REVIEW BY INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
- -----------------------------------------------------------------
With respect to the unaudited condensed consolidated financial
information of UniSource Energy and TEP for the three-month and six-month
periods ended June 30, 2004 and 2003, 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 August
19, 2004 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.
32
ITEM 2. - MANAGEMENT'S DISCUSSION 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 strategy,
o operating results during the second quarter and first six months of
2004 compared with the same periods in 2003,
o factors which affect our results and outlook,
o liquidity, capital needs, capital resources, and contractual
obligations,
o dividends, and
o critical accounting policies.
Management's Discussion and Analysis should be read in conjunction with
UniSource Energy and TEP's 2003 Form 10-K and with the Condensed Consolidated
Financial Statements, beginning on page 2, which present the results of
operations for the three months and six months ended June 30, 2004 and 2003.
Certain information in Management's Discussion and Analysis of Financial
Condition and Results of Operations for UniSource Energy and TEP has been
restated. For further information, see Note 1 of Notes to Condensed Consolidated
Financial Statements - Nature of Operations, Basis of Accounting and
Equity-Based Compensation. 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.
OVERVIEW OF CONSOLIDATED BUSINESS
UniSource Energy Corporation (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 Tucson Electric Power Company (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, provides gas and electric
service to 30 communities in northern and southern Arizona. Millennium invests
in unregulated businesses, including a developer of thin-film batteries and a
developer and manufacturer of thin-film photovoltaic cells. UED engages in
developing generating resources and other project development activities,
including facilitating the expansion of the Springerville Generating Station. We
conduct our business in these four primary business segments -- TEP's Electric
Utility Segment, UES' Gas and Electric Utility Segment, the Millennium
Businesses Segment, and the UED Segment.
TEP is the principal operating subsidiary of UniSource Energy and, at
June 30, 2004, represented approximately 85% of its assets. The seasonal nature
of TEP's business causes operating results to vary significantly from quarter to
quarter. UniSource Energy's results for the six months ended June 30, 2004
include two full quarters of operations of UES. UES was not in operation during
the first six months of 2003. Due to sales of both winter-peaking gas and
summer-peaking electricity, UES' consolidated operating results are expected to
be less seasonal than TEP's. Although representing approximately 5% of UniSource
Energy's total assets, results from Millennium's unregulated businesses had a
significant impact on earnings reported by UniSource Energy for the three and
six months ended June 30, 2004 and 2003. UED's unregulated business segment,
which was established in February 2001, had a significant impact on consolidated
net income and cash flows in the fourth quarter of 2003 since the financial
closing of Springerville Unit 3 occurred on October 21, 2003. UED did not have a
significant impact on net income or cash flow in the first or second quarters of
2003 or 2004, nor is it expected to in future periods.
33
OUTLOOK AND STRATEGIES
AGREEMENT AND PLAN OF MERGER
On November 21, 2003, UniSource Energy and Saguaro Acquisition Corp., a
Delaware corporation, entered into an acquisition agreement providing for the
acquisition of all of the common stock of UniSource Energy for $25.25 per share
by an affiliate of Saguaro Utility Group L.P., an Arizona limited partnership
(Saguaro Utility), whose general partner is Sage Mountain, L.L.C. and whose
limited partners include investment funds affiliated with Kohlberg Kravis
Roberts & Co., L.P., J.P. Morgan Partners, LLC and Wachovia Capital Partners.
Frederick B. Rentschler is the managing member of Sage Mountain L.L.C., an
Arizona limited liability company.
Pursuant to the terms of the acquisition agreement, Saguaro Acquisition
Corp., a wholly-owned and indirect subsidiary of Saguaro Utility, will merge
with and into UniSource Energy. UniSource Energy will be the surviving
corporation, but will become an indirect wholly-owned subsidiary of Saguaro
Utility. Trading in our stock on the New York Stock Exchange and the Pacific
Exchange will cease immediately as of the effective time of the acquisition.
After that time, the surviving corporation will delist our shares from the New
York Stock Exchange and the Pacific Exchange and de-register our shares under
the Securities Exchange Act of 1934, as amended. UniSource Energy's and TEP's
headquarters will remain in Tucson, and we expect that UniSource Energy's and
TEP's senior management team will remain generally the same.
Upon the closing of the acquisition, Saguaro Utility will cause the
surviving corporation to pay approximately $880 million in cash to UniSource
Energy's shareholders and holders of stock options, stock units, restricted
stock and performance shares awarded under our stock-based compensation plans.
In connection with the closing of the acquisition, Saguaro Utility intends to
cause the surviving corporation (i) to repay the $95 million inter-company loan
to UniSource Energy from TEP and (ii) to contribute up to $168 million to TEP.
TEP will use a significant portion of these proceeds to retire some of its
outstanding debt.
On March 25, 2004, an affiliate of Saguaro Utility entered into a $410
million credit agreement in connection with a commitment obtained by Saguaro
Utility from lenders in November 2003. The credit agreement will be funded upon
closing of the acquisition of UniSource Energy. It includes a $50 million
revolving credit facility for general corporate purposes and a $360 million term
loan to be used to fund a portion of the acquisition. The lenders' obligations
to make such loans are subject to various closing conditions customary for
credit facilities to be used in an acquisition of this type.
UniSource Energy's shareholders approved the acquisition agreement at a
special meeting on March 29, 2004. The acquisition still requires approval by
the Arizona Corporation Commission (ACC), the Securities and Exchange Commission
(SEC) under the Public Utility Holding Company Act and the Federal Regulatory
Commission (FERC) under the Federal Power Act, and the satisfaction of other
conditions set forth in the acquisition agreement. UniSource Energy filed an
application with the ACC for approval of the acquisition on December 29, 2003.
The waiting period under the Hart-Scott-Rodino Antitrust Improvement Act was
terminated on March 19, 2004. Saguaro Utility filed an application with the SEC
for approval of the acquisition on March 30, 2004. On April 7, 2004, UniSource
Energy and Saguaro Utility filed a joint application with FERC under the Federal
Power Act for approval of the acquisition.
Public hearings on the ACC application were conducted before an
administrative law judge (ALJ) and concluded on July 1, 2004. In its testimony
before the ALJ, the staff of the ACC stated that UniSource Energy had addressed
many of the concerns raised in its initial testimony filed on April 30, 2004.
Staff indicated its continued concern regarding a few remaining issues related
to financial protection of the utility businesses from UniSource Energy and
service quality and reliability. However, staff indicated it would adopt a
neutral position on the acquisition if certain conditions were met. The
Residential Utility Consumer Office (RUCO) filed initial testimony on April 30,
2004, participated in the ALJ hearings and continues to oppose the acquisition.
Since the conclusion of the hearing, all parties have filed initial briefs and
reply briefs with the ALJ that supported their respective positions.
Subject to the receipt of the required regulatory approvals and the
satisfaction of the other closing conditions contained in the acquisition
agreement, we expect to close the transaction in the fourth quarter of 2004.
34
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 Obtain all necessary regulatory approvals and satisfy all of the other
closing conditions contained in the acquisition agreement so that the
acquisition of UniSource Energy by an affiliate of Saguaro Utility can
occur in a timely manner.
o Integrate UES' businesses with UniSource Energy's other businesses to
achieve the strategic and financial objectives of the acquisition.
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.
o Enhance the value of TEP's transmission system while continuing to
provide reliable access to generation for TEP's retail customers and
market access for all generating assets. This will include focusing on
completing the Tucson - Nogales transmission line, which could
eventually be connected to Mexico's utility system and improve
reliability for customers of UNS Electric.
o Continue to manage our existing Millennium investments to maximize
their value.
o Increase production and sales of Global Solar's thin-film photovoltaic
cells and seek strategic partners.
o Reduce TEP's debt, using some of our excess cash flows.
o Efficiently manage TEP's generating resources and look for ways to
reduce or control our operating expenses while maintaining and
enhancing reliability and profitability.
To accomplish our goals, during 2004 we expect TEP to spend
approximately $106 million on capital expenditures and UES to spend
approximately $37 million on capital expenditures. As of June 30, 2004,
year-to-date capital expenditures were $53 million and $18 million for TEP and
UES, respectively.
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.
UNISOURCE ENERGY CONSOLIDATED
RESULTS OF OPERATIONS
Three Months Ended June 30, 2004 Compared with the Three Months Ended June 30,
2003
UniSource Energy recorded net income of $13 million, or $0.37 per
average share of Common Stock, in the second quarter of 2004 compared with net
income of $7 million, or $0.20 per average share of Common Stock last year. The
following factors contributed to the change in net income:
o A $14 million increase in TEP's utility gross margin (the sum of
electric retail revenues and electric wholesale revenues less fuel
expense and purchased power expense) resulting from:
- - a $12 million increase in TEP's retail revenues resulting from a
2% increase in the retail customer base and higher energy demand;
- - a $7 million increase in TEP's wholesale revenues resulting from
higher wholesale kWh sales and higher wholesale power prices compared
to last year when generating plant outages limited wholesale
opportunities (net of a $3 million reserve for refund recorded in
the second quarter of 2004 related to wholesale kWh sales made to
California during 2000 and 2001); offset by
35
- - a $4 million increase in fuel expense due to the higher availability
and use of TEP's coal-fired generating facilities and a 9% increase
in gas-fired generation; and
- - a $1 million increase in TEP's purchased power expense.
Other factors contributing to the change in UniSource Energy's net
income in the second quarter of 2004 compared with the same period last year
include:
o A $6 million increase in income tax expense due to higher pre-tax
income;
o a $4 million scheduled increase in TEP's amortization of transition
recovery asset;
o a $2 million increase in TEP's depreciation and amortization due to
increased plant in service;
o a $3 million decrease in TEP's total interest expense resulting from
lower fees and rates associated with TEP's Credit Facility that was
refinanced in March 2004, as well as lower capital lease interest
expense;
o net income of less than $1 million at UES;
o $1 million of lower net losses at MEH;
o a $1 million net loss at UED related to the write-off of a note
receivable; and
o expenses of $1 million related to the proposed acquisition of UniSource
Energy.
Six Months Ended June 30, 2004 Compared with the Six Months Ended June 30, 2003
UniSource Energy recorded net income of $19 million, or $0.56 per
average share of Common Stock, in the first six months of 2004 compared with net
income of $59 million, or $1.75 per average share of Common Stock last year.
Results in the first six months of 2003 include an after-tax gain of $67
million, or $2.00 per average share of Common Stock, for the Cumulative Effect
of Accounting Change from the adoption of Statement of Financial Accounting
Standards No. 143, Accounting for Asset Retirement Obligations (FAS 143). The
net loss before the Cumulative Effect of Accounting Change was $8 million, or
$0.25 per average share of Common Stock. The following factors contributed to
the change in net income (loss) before the Cumulative Effect of Accounting
Change:
o A $38 million increase in TEP's utility gross margin (the sum of
electric retail revenues and electric wholesale revenues, less fuel
expense and purchased power expense) resulting from:
- - a $26 million increase in retail revenues resulting from cold
weather during January and February, and a 2% increase in the
retail customer base;
- - an $8 million increase in wholesale revenues resulting from higher
wholesale kWh sales and higher wholesale power prices compared to
last year when generating plant outages limited wholesale
opportunities (net of a $3 million reserve for refund recorded in the
second quarter of 2004 related to wholesale kWh sales made to
California during 2000 and 2001); and
- - an $8 million decline in purchased power expense resulting from fewer
planned and unplanned outages at TEP's generating facilities,
reducing the need to purchase replacement power to meet retail
demand; partially offset by:
- - a $5 million increase in fuel expense due to the higher availability
and use of TEP's coal-fired generating facilities and increased use
of gas-fired generation.
Other factors contributing to the change in UniSource Energy's net
income in the first six months of 2004
36
compared with the same period last year include:
o a $9 million scheduled increase in TEP's amortization of transition
recovery asset;
o a $3 million decrease in TEP's total interest expense resulting from
lower fees and rates associated with TEP's Credit Facility that was
refinanced in March 2004, as well as lower capital lease interest
expense;
o a $3 million increase in TEP's depreciation and amortization due to
increased plant-in-service;
o net income of $5 million at UES;
o $8 million of lower net losses at MEH resulting from income of $3
million (net of tax) recorded in the first quarter of 2004 related to
Haddington Energy Partners II, LP, (Haddington) one of Millennium's
equity method investments, and lower operating costs at Global Solar
and IPS;
o a $1 million net loss at UED related to the write-off of a note
receivable;
o a $20 million increase in income tax expense due to higher pre-tax
income; and
o expenses of $3 million related to the proposed acquisition of UniSource
Energy.
CONTRIBUTION BY BUSINESS SEGMENT
The table below shows the contributions to our consolidated after-tax
earnings (losses) by our four business segments, as well as parent company
expenses.
<table>
Three Months Ended Six Months Ended
June 30, June 30,
2004 2003 2004 2003
Restated(1) Restated (1)
------------------------------------------------------------ -------------- ------------- ------------- --------------
Business Segment - Millions of Dollars - - Millions of Dollars -
TEP (2) $ 18 $ 14 $ 19 $ 73
UES (3) - - 5 -
UED (1) - (1) -
Millennium (3) (4) (1) (9)
UniSource Energy Standalone (4) (1) (3) (3) (5)
------------------------------------------------------------ -------------- ------------- ------------- --------------
Consolidated Net Income $ 13 $ 7 $19 $ 59
============================================================ ============== ============= ============= ==============
<fn>
(1) See Note 1 of Notes to Condensed Consolidated Financial Statements
(2) TEP results in the first six months of 2003 include an after-tax gain
of $67 million for the Cumulative Effect of Accounting Change from the
adoption of FAS 143.
(3) UES began operations in August 2003.
(4) Primarily represents interest expense (net of tax) on the note payable
from UniSource Energy to TEP.
</fn>
</table>
37
<table>
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
UNISOURCE ENERGY CONSOLIDATED CASH FLOWS
Six Months Ended June 30, 2004 2003
---------------------------------------- ------------------------ -------------------------
- Millions of Dollars -
Cash Provided by (Used in):
Operating Activities $ 138 $ 44
Investing Activities (57) (62)
Financing Activities (53) (28)
---------------------------------------- ------------------------ -------------------------
Net Increase/(Decrease) in Cash $ 28 $ (46)
======================================== ======================== =========================
</table>
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. Typically, 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 and UES;
o make investments in our technology affiliates;
o pay dividends to shareholders; and
o reduce leverage at TEP by repaying high coupon 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, from
their cash flow from operations. See Tucson Electric Power Company, Liquidity
and Capital Resources, Dividends, below.
Accrued interest on UniSource Energy's promissory note to TEP of
approximately $20 million is payable every two years; the last payment of $20
million was made to TEP in December 2003. Under our tax allocation procedures
our subsidiaries make income tax payments to UniSource Energy, which makes
payments on behalf of the consolidated group.
As of August 18, 2004, cash and cash equivalents available to UniSource
Energy was approximately $131 million.
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).
Operating Activities
In the first six months of 2004, net cash flows from operating
activities increased by $94 million compared with the same period in 2003. The
following factors contributed to the increase:
o a $118 million increase in cash receipts from retail and wholesale
energy customers, net of fuel and purchased energy costs, due to
energy sales at UES and increased retail and wholesale electric
sales at TEP; and
o the return of a $17 million deposit related to TEP's second mortgage
indenture; partially offset by
o a $21 million increase in other taxes paid due primarily to property,
sales and use taxes paid at UES;
o a $ 4 million increase in income taxes due to a larger final tax
payment related to prior year consolidated income tax returns;
38
o an $18 million increase in O&M due to $15 million of O&M at UES and
acquisition-related costs; and
o an $8 million increase in wages paid due primarily to $6 million of
wages paid at UES and incentive compensation payments to management
pursuant to their employment arrangements triggered by the shareholder
approval of the proposed acquisition of UniSource Energy.
Investing Activities
Net cash used for investing activities was $5 million lower in the
first six months of 2004 compared with the same period in 2003, due primarily to
a $10 million return of investment from one of MEH's businesses partially offset
by a $4 million investment in Springerville Lease Debt made in the first quarter
of 2004.
Financing Activities
Net cash used for financing activities was $25 million higher in the
first six months of 2004 compared with the same period in 2003. The following
factors contributed to the increase:
o a repayment of $20 million on borrowings under TEP's Revolving Credit
Facility;
o TEP paid $9 million in debt issue costs related to the refinancing of
its Credit Agreement; and
o a $5 million increase in scheduled payments for TEP's capital lease
obligations; partially offset by:
o an increase in other cash inflows of $10 million related to cash
received from stock option exercises and new TEP and UES customer
deposits.
Our consolidated cash and cash equivalents increased to $129 million at
June 30, 2004, from $61 million at March 31, 2004. We invest cash balances in
high-grade money market securities with an emphasis on preserving the principal
amounts invested.
In the event that we experience lower cash from operations in 2004, we
may 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.
TEP redeemed $27 million of 8.5% First Mortgage Bonds (due in 2009) on
July 7, 2004. This transaction will result in annual pre-tax savings of $2
million.
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 entered 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' Arizona gas
and electric system assets, UniSource Energy's guarantee of approximately $24
million in natural gas and supply payments and building lease payments for UNS
Gas and UES, and Millennium's guarantee of approximately $3 million in
commodity-related payments for MEG at June 30, 2004. 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, UES or Millennium
would be required to perform or otherwise incur any significant losses
associated with any of these guarantees is remote.
39
CONTRACTUAL OBLIGATIONS
There have been no significant changes in our contractual obligations
or other commercial commitments from those reported in our 2003 Annual Report on
Form 10-K.
DIVIDENDS ON COMMON STOCK
The following table shows the declared dividends to UniSource Energy
shareholders for 2004.
<table>
Dividend Amount
Declaration Date Record Date Payable Date Per Share of Common Stock
- ----------------------------------------------------------------------------------------------------------------------------
February 6, 2004 February 17, 2004 March 10, 2004 $0.16
May 7, 2004 May 18, 2004 June 10, 2004 $0.16
- ----------------------------------------------------------------------------------------------------------------------------
</table>
The acquisition agreement allows UniSource Energy to continue to pay
regular quarterly cash dividends until the closing of the acquisition, subject
to limitations upon our ability to increase the amount of such dividends.
UniSource Energy's Board of Directors currently expects to continue to pay
regular quarterly cash dividends on UniSource Energy's Common Stock until the
closing of the acquisition, subject, however, to its evaluation of our financial
condition, earnings, cash flows and dividend policy.
INCOME TAX POSITION
At June 30, 2004, UniSource Energy and TEP had, for federal and state
income tax filing purposes, the following carryforward amounts. These amounts
represent balances resulting from federal returns filed (or extended) as of
December 31, 2003.
<table>
UniSource Energy TEP
Amount Expiring Amount Expiring
-Millions of Dollars- Year -Millions of Dollars- Year
- -------------------------------------------------------------------------------------------------------
Net Operating Losses $ 55 2006-2023 $ 32 2006-2009
Investment Tax Credit 8 2004-2023 8 2004-2023
AMT Credit 88 - 85 -
- -------------------------------------------------------------------------------------------------------
</table>
Of the $55 million in NOL carryforwards at UniSource Energy, $18
million is subject to limitation due to a reorganization of certain Millennium
entities in December 2002. The future use of these losses is dependent upon the
generation of sufficient future taxable income at the separate company level.
See Critical Accounting Policies, 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. The following discussion relates to TEP's
utility operations, unless otherwise noted.
TEP kWh Sales and Revenues
Customer growth, weather and other consumption factors affect retail
sales of electricity. Electric wholesale revenues are affected by market prices
in the wholesale energy market, availability of TEP generating resources, the
price of fuel, and the level of wholesale forward contract activity.
TEP kWh sales delivered and corresponding revenues for the quarter
ended and six months ended June 30, 2004 compared with the same periods in 2003
are detailed below.
40
<table>
Sales Operating Revenue
----------------------------------------------------------------------------------------------------------------------------
2003 Percent 2003 Percent
Three Months Ended June 30, 2004 Restated (1) Change 2004 Restated (1) Change
----------------------------------------------------------------------------------------------------------------------------
- Millions of kWh - - Millions of Dollars -
Electric Retail Sales:
Residential 826 786 5% $ 81 $ 76 7%
Commercial 478 446 7% 51 47 9%
Industrial 603 601 - 43 42 2%
Mining 205 173 18% 9 7 29%
Public Authorities 66 72 (8%) 5 5 -
----------------------------------------------------------------------------------------------------------------------------
Total Electric Retail Sales 2,178 2,078 5% $189 $177 7%
----------------------------------------------------------------------------------------------------------------------------
Electric Wholesale Sales Delivered:
Long-term Contracts 282 258 9% 13 12 8%
Other Sales 654 537 22% 27 21 29%
Transmission - - - 2 2 -
----------------------------------------------------------------------------------------------------------------------------
Total Electric Wholesale Sales 936 795 18% 42 35 20%
----------------------------------------------------------------------------------------------------------------------------
Total 3,114 2,873 8% $231 $212 9%
============================================================================================================================
<fn>
(1) See Note 1 of Notes to Condensed Consolidated Financial Statements
</fn>
</table>
TEP's retail customer base increased by 2% to 370,413, while kWh sales
to retail customers increased by 5% in the second quarter of 2004 compared with
the same period last year. Kilowatt-hour sales to residential customers were up
5% and kWh sales to commercial customers were up 7%, primarily resulting from
customer growth. Copper prices were 65% higher in the second quarter of 2004
compared with the same period in 2003, leading to increased mining activity and
an 18% increase in kWh sales to TEP's mining customers. Revenues from TEP's
mining customers increased $2 million, benefiting from increased demand and
higher prices for copper. The price of energy provided to TEP's mining customers
is indexed with the market price of copper. Total revenues from kWh sales to
retail customers increased by $12 million in the second quarter of 2004
resulting from higher energy demand. See Critical Accounting Policies, Unbilled
Revenue, below.
Wholesale kWh sales were up 18% and wholesale revenues were up 20%
compared with the second quarter of 2003, due to increased sales activity and
higher wholesale power prices. Greater coal plant availability in the second
quarter of 2004 allowed TEP to sell more excess power into the wholesale market.
The average price of power on the Dow Jones Palo Verde Index was $44 per MWh in
the second quarter of 2004, compared with $39 per MWh in the same period last
year. TEP recorded a $3 million reserve in the second quarter of 2004 for
revenue subject to refund related to wholesale sales made to the California
Independent System Operator (CISO) and the California Power Exchange (CPX) in
2001 and 2000. This amount was recorded as a reduction to wholesale revenue. See
Critical Accounting Policies, TEP - Payment Defaults and Allowances for Doubtful
Accounts, below.
41
<table>
Sales Operating Revenue
----------------------------------------------------------------------------------------------------------------------------
2003 Percent 2003 Percent
Six Months Ended June 30, 2004 Restated (1) Change 2004 Restated (1) Change
----------------------------------------------------------------------------------------------------------------------------
- Millions of kWh - - Millions of Dollars -
Electric Retail Sales:
Residential 1,544 1,428 8% $139 $129 8%
Commercial 836 772 8% 87 80 9%
Industrial 1,093 1,068 2% 79 76 4%
Mining 398 325 22% 18 13 38%
Public Authorities 116 123 (6%) 9 8 13%
----------------------------------------------------------------------------------------------------------------------------
Total Electric Retail Sales 3,987 3,716 7% $332 $306 8%
----------------------------------------------------------------------------------------------------------------------------
Electric Wholesale Sales Delivered:
Long-term Contracts 628 587 7% 28 26 8%
Other Sales 1,197 1,147 4% 52 46 13%
Transmission - - - 4 3 33%
----------------------------------------------------------------------------------------------------------------------------
Total Electric Wholesale Sales 1,825 1,734 5% 84 75 12%
----------------------------------------------------------------------------------------------------------------------------
Total 5,812 5,450 7% $416 $381 9%
============================================================================================================================
<fn>
(1) See Note 1 of Notes to Condensed Consolidated Financial Statements
</fn>
</table>
Total retail kWh sales increased by 7% in the first six months of 2004.
Kilowatt-hour sales to residential and commercial customers were both up 8%,
resulting from customer growth and a 28% increase in first quarter 2004
heating-degree days. The average price of copper was 64% higher in first six
months of 2004, leading to increased mining activity and a 22% increase in kWh
sales to TEP's mining customers. Revenues from TEP's mining customers increased
$5 million in the second quarter of 2004, benefiting from increased demand and
higher prices for copper. Total revenues from kWh sales to retail customers
increased by $26 million in the first six months of 2004, resulting from higher
energy demand.
Wholesale kWh sales were up 5% and wholesale revenues were up 12% in
the first six months of 2004. Greater coal plant availability allowed TEP to
sell more excess power into the wholesale market. TEP recorded a $3 million
reserve in the second quarter of 2004 and a $2 million reserve in the first
quarter of 2003 for revenue subject to refund related to wholesale sales made to
CISO and the CPX in 2001 and 2000. These amounts are recorded as a reduction to
wholesale revenue. See Critical Accounting Policies, TEP - Payment Defaults and
Allowances for Doubtful Accounts, below.
Fuel and Purchased Power Expenses
TEP's fuel and purchased power expense, and energy resources for the
second quarter and first six months of 2004 compared with the same periods of
2003 are detailed in the tables below:
42
<table>
Generation Expense
- ---------------------------------------- -------------------------------- -----------------------------------
Percent Percent
Three Months Ended June 30, 2004 2003 Change 2004 2003 Change
- ---------------------------------------- ------- ---------- ------------- --------- --------- ---------------
-Millions of kWh- -Millions of Dollars-
Coal-Fired Generation 2,910 2,646 10% $47 $44 7%
Gas- Fired Generation 98 90 9% 8 7 14%
- ---------------------------------------- ------- ---------- ------------- --------- --------- ---------------
Total Generation 3,008 2,736 10% 55 51 8%
Purchased Power 328 352 (7%) 19 18 6%
- ---------------------------------------- ------- ---------- ------------- --------- --------- ---------------
Total Resources 3,336 3,088 8% $74 $69 7%
Less Losses and Company Use 222 215 3%
- ---------------------------------------- ------- ---------- ------------- ========= ========= ===============
Total Energy Sold 3,114 2,873 8%
======================================== ======= ========== =============
</table>
Fuel expense at TEP's generating plants increased by $4 million, or 8%,
in the second quarter of 2004, due to the higher availability and use of TEP's
coal-fired generating facilities and increased gas-fired generation. During the
first six months of 2003, many of TEP's coal-fired generating facilities
underwent major planned outages, as well as unplanned outages, limiting their
availability to meet retail and wholesale energy demand. In the second quarter
of 2004, generation at TEP's coal-fired units was up 10%, or 264 million kWh,
compared with the second quarter of 2003. The average cost of fuel per kWh
generated for the second quarter of 2004 was 1.84 cents, compared with 1.89
cents in the same period last year.
TEP's Purchased Power expense increased $1 million, or 6%, in the
second quarter of 2004, due to higher wholesale power prices. TEP purchased 7%
less energy, or 24 million kWh, in the second quarter of 2004; however,
wholesale power prices were 13% higher. See Wholesale Energy Markets - Energy
Prices, below.
<table>
Generation Expense
- --------------------------------------- --------------------------------- -----------------------------------
Percent Percent
Six Months Ended June 30, 2004 2003 Change 2004 2003 Change
- --------------------------------------- -------- ---------- ------------- --------- --------- ---------------
-Millions of kWh- -Millions of Dollars-
Coal-Fired Generation 5,673 4,969 14% $ 94 $ 83 13%
Gas- Fired Generation 110 194 (43%) 9 15 (40%)
- --------------------------------------- -------- ---------- ------------- --------- --------- ---------------
Total Generation 5,783 5,163 12% 103 98 5%
Purchased Power 424 657 (35%) 25 33 (24%)
- --------------------------------------- -------- ---------- ------------- --------- --------- ---------------
Total Resources 6,207 5,820 7% $128 $131 (2%)
Less Losses and Company Use 395 370 7%
- --------------------------------------- -------- ---------- ------------- ========= ========= ===============
Total Energy Sold 5,812 5,450 7%
======================================= ======== ========== =============
</table>
In the first six months of 2004, fuel expense increased by $5 million,
or 5%, due to the higher availability of and use of TEP's coal-fired generating
facilities. Generation at TEP's coal-fired units was up 14%, or 704 million kWh,
compared with the first six months of 2003. See Item 3. - Quantitative and
Qualitative Disclosures About Market Risk, below.
Purchased power expense declined by $8 million, or 24%, in the first
six months of 2004 compared with the same period last year. The higher
availability of TEP's coal-fired resources reduced the need to purchase
replacement power.
Other Operating Expenses
Other Operations and Maintenance expense (O&M) increased by $2 million,
or 4%, in the second quarter of 2004, and $4 million, or 5% in the first six
months of 2004, compared with the same periods last year. The
43
increases are due primarily to TEP's allocated portion of acquisition-related
costs. Through June 30, 2004, TEP has expensed $2 million of acquisition-related
costs. In addition, $2 million was expensed and paid in incentive compensation
resulting from shareholder approval of the acquisition on March 29, 2004.
Amortization of the Transition Recovery Asset (TRA) increased $4
million in the second quarter of 2004, and $9 million in the first six months of
2004, compared with the same periods in 2003. 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. TEP expects TRA amortization to be $49 million in 2004,
$57 million in 2005, $66 million in 2006, $76 million in 2007 and $26 million in
2008.
Other Income (Deductions)
TEP's income statement includes inter-company interest income of $2
million for the second quarter of 2004 compared with $3 million for the same
period in 2003. This represents Interest Income on the 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 income statement, this
Interest Income, as well as UniSource Energy's related interest expense, is
eliminated as an inter-company transaction. Inter-company interest income was $5
million in the first six months of 2004.
Interest Expense
Total interest expense decreased by $3 million, or 8%, in the second
quarter of 2004, resulting from the refinancing of TEP's Credit Agreement in
March 2004 and a $1 million decrease in capital lease interest expense. Interest
on capital leases was lower in the second quarter of 2004 due to scheduled
repayments of capital lease obligations. Total interest expense decreased by $3
million, or 3%, in the first six months of 2004. Unamortized fees of $2 million
that were expensed in the first quarter of 2004 as a result of the refinancing
of TEP's Credit Agreement were offset by the lower rates and fees associated
with the new Credit Agreement, as well as a $1 million decrease in capital lease
interest expense. See Liquidity and Capital Resources, TEP Cash Flows, Investing
Activities, TEP Credit Agreement, below.
Income Tax Expense
Income tax expense, before Cumulative Effect of Accounting Change,
increased $5 million in the second quarter of 2004, compared with the same
period in 2003, due to higher pre-tax income. In the first six months of 2004,
Income Tax Expense increased by $11 million compared with the same period in
2003, due to higher pre-tax income.
Cumulative Effect of Accounting Change
TEP adopted FAS 143 on January 1, 2003 and recorded a one-time $67
million after-tax gain. Upon adoption of FAS 143, TEP recorded an asset
retirement obligation of $38 million at its net present value of $1 million;
increased depreciable assets by $0.1 million for asset retirement costs,
reversed $113 million of costs previously accrued for final removal from
accumulated depreciation, and reversed previously recorded deferred tax assets
of $44 million. The adoption of FAS 143 resulted in a reduction to depreciation
expense charged throughout the year because asset retirement costs are no longer
recorded as a component of depreciation expense. See Critical Accounting
Policies - Accounting for Asset Retirement Obligations, below.
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 experience in California with
deregulation during 2000 and 2001 has caused many states, including Arizona, to
re-examine the viability of retail electric deregulation.
44
As of January 1, 2001, all of TEP's retail customers became eligible to
choose an alternate energy supplier. Although there is one Energy Service
Provider (ESP) certified to provide service in TEP's retail service area,
currently none of TEP's retail customers are receiving service from this ESP.
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.
On January 27, 2004, the Arizona Court of Appeals issued a decision
that addressed challenges to the ACC's Retail Electric Competition Rules. The
Court determined that certain rules established by the ACC relating to the entry
of new competitive electric services providers into the market were invalid. The
ultimate impact on TEP's Settlement Agreement is not known. Motions for
Reconsideration, which is a prerequisite to filing an appeal, were filed by
several Arizona electric cooperatives. On May 4, 2004, Trico Electric
Cooperative filed a Petition for Review at the Arizona Supreme Court.
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
In 1999, the ACC approved the TEP Settlement Agreement between TEP and
certain customer groups related to the implementation of retail electric
competition. The TEP Settlement Agreement provided for certain retail rate
reductions from 1998 through 2000. In addition, TEP was required to file with
the ACC by June 1, 2004 general rate case information, including an updated cost
of service study. Under the terms of the TEP Settlement Agreement, no rate case
filed by TEP through 2008, including the filing on June 1, 2004, may result in a
rate increase. Any rate decrease resulting from the 2004 filing would be
effective no earlier than June 1, 2005.
On June 1, 2004, TEP filed general rate case information with the ACC.
TEP's filing does not propose any change in retail rates. Absent the restriction
on raising rates provided in the TEP Settlement Agreement, the data presented by
TEP would justify a request by TEP for 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 $115 million. The proposed weighted cost of
capital for the test year ended December 31, 2003 is 8.78%, including an 11.5%
return on equity.
TEP has requested a procedural conference with the ACC to discuss how
the review of the general rate case information will proceed.
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.
The generating capacity in Arizona is expected to be approximately
24,000 MW by the end of 2004, which represents an increase of 55% compared with
the capacity available at the end of 2000. A majority of this growth is the
result of 16 new or upgraded gas-fired generating units with a combined capacity
of approximately 8,500 MW. In addition, the presence of fewer creditworthy
counterparties, as well as legal, political and regulatory uncertainties, has
reduced market liquidity and trading volume.
45
Market Prices
The average market price for around-the-clock energy based on the Dow
Jones Palo Verde Index increased in the second quarter of 2004 compared with
2003, as did the average prices for natural gas based on the Permian Index.
Beginning in January 2004, all natural gas used by TEP plants originated from
the Permian Gas Basin.
<table>
Average Market Price for Around-the-Clock Energy $/MWh
------------------------------------------------------------------ -------------
Quarter Ended June 30, 2004 $44
Quarter Ended June 30, 2003 39
Six Months Ended June 30, 2004 $42
Six Months Ended June 30, 2003 42
Average Market Price for Natural Gas $/MMBtu
------------------------------------------------------------------ -------------
Quarter Ended June 30, 2004 $5.39
Quarter Ended June 30, 2003 4.94
Six Months Ended June 30, 2004 $5.21
Six Months Ended June 30, 2003 5.35
</table>
Natural gas prices remained at historically high levels throughout 2003
and into 2004 with continued demand, storage and production concerns. These high
gas and subsequent power prices are currently expected to continue at least for
the near-term period. Starting in July 2004, the average forward
around-the-clock market price at Palo Verde for the balance of the year 2004 is
estimated at approximately $50 per MWh, based on forward market broker quotes as
of June 30, 2004. As a result, we expect TEP's fuel and purchased power expense
to be higher in 2004 than in 2003, depending on the actual volumes purchased. 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 again
during the remainder of 2004.
We expect the market price and demand for capacity and energy to
continue to be influenced by the following factors during the next few years:
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 restrictions and the cost of compliance.
Payment Defaults and Allowances for Doubtful Accounts
See Critical Accounting Policies, TEP - Payment Defaults and Allowances
for Doubtful Accounts, below.
46
GENERATING RESOURCES
Water Supply
Drought conditions in the Four Corners region, combined with water
usage in upper New Mexico, have resulted in decreasing water levels in the lake
that indirectly supplies water to the San Juan and Four Corners generating
stations. These drought conditions may affect the water supply of the plants if
adequate moisture is not received in the watershed that supplies the area. TEP
has a 50% ownership interest in each of San Juan Units 1 and 2 (322 MW capacity)
and a 7% ownership interest in each of Four Corners Units 4 and 5 (110 MW
capacity).
The Operating Agents for the plants have negotiated supplemental water
contracts with the U.S. Bureau of Reclamation and the Jicarilla Apache Nation
for 2004 to assist the plants in meeting its water requirements in the event of
a water shortage. Additionally, negotiations are underway for supplemental
contracts for later years. The Operating Agents indicate that plant operations
will not be materially affected in 2004. However, TEP cannot predict the
ultimate outcome of the drought, or whether it will adversely affect the amount
of power available from the San Juan and Four Corners generating stations.
<table>
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
TEP CASH FLOWS
Six Months Ended June 30, 2004 2003
---------------------------------------------------------------- ----------------- -----------------
-Millions of Dollars-
Cash from Operations $ 116 $ 63
Capital Expenditures (53) (67)
Debt Maturities (1) (1)
Retirement of Capital Lease Obligations (44) (38)
---------------------------------------------------------------- ----------------- -----------------
Net Cash Flows Available after Required Payments $ 18 $(43)
================================================================ ================= =================
</table>
Cash from operations typically is the lowest in the first quarter and
highest in the third quarter due to TEP's summer peaking load. TEP's capital
requirements consist primarily of capital expenditures and optional and
mandatory redemptions of long-term debt and capital lease obligations.
During 2004, 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 energy prices, natural gas prices, availability of
coal-fired generation, changes in short-term interest rates, and 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.
Operating Activities
In the first six months of 2004, net cash flows from operating
activities increased by $53 million compared with the same period in 2003. The
following factors contributed to the increase:
o a $46 million increase in cash receipts from retail and wholesale
electric customers, net of fuel and purchased energy costs, due
primarily to higher retail energy demand and lower fuel and purchased
power costs;
o the return of a $17 million deposit related to TEP's second mortgage
indenture; and
o a $5 million decrease in total interest paid due to lower interest
rates on TEP's Credit Facility, which was refinanced in March
2004, and lower capital lease obligations outstanding; partially
offset by:
47
- - a $6 million increase in income taxes paid due to higher estimated
taxable income for 2004;
- - a $4 million increase in O&M costs due to costs related to the
acquisition of UniSource Energy by Saguaro Utility Group L.P.; and
- - a $4 million increase in wages paid due to higher incentive
compensation.
Investing Activities
Net cash used for investing activities was $11 million lower in the
first six months of 2004 compared with the same period in 2003, due primarily to
a $15 million decline in capital expenditures, partially offset by a $4 million
investment in Springerville Lease Debt. Lower capital expenditures at TEP are
primarily the result of the timing of expected projects. We expect TEP's capital
expenditures to be approximately $106 million in 2004.
TEP has sought approvals for construction of a 345-kV transmission line
that would extend from Tucson to Nogales, Arizona, and into northern Mexico. The
ACC approved a route for the line in January 2002, but the U.S. Forest Service
has since indicated its preference for an alternate route not approved by the
ACC. As a result, the ACC has ordered TEP to re-open the state line siting
process and to engage in discussions of potential alternatives to the line.
Through June 30, 2004, approximately $9 million in engineering and environmental
expenses have been capitalized related to this project. If the transmission line
does not proceed and the regulators decline to provide for recovery of such
costs through rates, these costs would be immediately expensed.
Financing Activities
Net cash used for financing activities was $18 million higher in the
second quarter of 2004 compared with the same period in 2003. The following
factors contributed to the increase:
o a repayment of $20 million on borrowings under TEP's Revolving Credit
Facility;
o $9 million paid in debt issue costs related to the refinancing of its
Credit Agreement; and
o $5 million increase in scheduled payments for capital lease
obligations; partially offset by:
- - an increase in other cash inflows of $8 million related to interest
received on the inter-company note to UniSource Energy and new
customer deposits; and
- - a decrease of $8 million in dividends paid by TEP to UniSource
Energy.
TEP redeemed $27 million of 8.5% First Mortgage Bonds (due in 2009) on
July 7, 2004. This transaction will result in annual pre-tax savings of $2
million.
TEP Credit Agreement
--------------------
On March 25, 2004, TEP entered into a new $401 million credit
agreement. The agreement replaces the credit facilities provided under TEP's
$401 million credit agreement that would have expired in 2006. The new credit
agreement includes a $60 million revolving credit facility for general corporate
purposes and a $341 million letter of credit facility, to support $329 million
aggregate principal amount of tax-exempt variable rate bonds. The credit
agreement has a five-year term, expiring June 30, 2009, and is secured by $401
million in aggregate principal amount of Second Mortgage Bonds issued under
TEP's General Second Mortgage Indenture.
The credit agreement contains a number of restrictive covenants,
including restrictions on additional indebtedness, liens, sale of assets and
sale-leasebacks. The credit agreement also contains several financial covenants
including: (a) minimum consolidated tangible net worth, (b) a minimum cash
coverage ratio, and (c) a maximum leverage ratio. Under the terms of the credit
agreement, TEP may pay dividends so long as it maintains compliance with the
credit agreement. The previous credit agreement had provided that dividends
could not
48
exceed 65% of TEP's net income. The elimination of such covenant is expected to
satisfy, in part, one of the closing conditions contained in the acquisition
agreement that UniSource Energy entered into with Saguaro Acquisition Corp., by
permitting TEP to dividend all of its net income to its shareholders. The credit
agreement also provides that under certain circumstances, certain regulatory
actions could result in a required reduction of the commitments.
The letter of credit fee of 2.35% on the new facility is significantly
lower than the previous credit agreement's weighted average letter of credit fee
of approximately 5%. The agreement also provides for letter of credit fronting
fees of 0.25%, which will reduce to 0.125% upon the closing of Saguaro's
acquisition of UniSource Energy; the previous agreement's fronting fee was
0.25%. Unreimbursed drawings on a letter of credit bear a variable rate of
interest based on LIBOR plus 2.25% per annum. Interest savings in 2004 will be
partially offset by the March 2004 write-off of $2 million of fees associated
with the prior facility that were capitalized and being amortized through 2006
and the amortization of $9 million of fees associated with the entry of the new
facility.
If TEP borrows under the revolving credit facility, the borrowing costs
would be at a variable interest rate consisting of a spread over LIBOR or an
alternate base rate. The spread is based upon a pricing grid tied to TEP's
leverage. The per annum rate currently in effect on borrowings under TEP's
revolving credit facility, based on its leverage, is LIBOR plus 2.25%. If TEP's
leverage were to change, the spread over LIBOR could range from 1.50% to 2.25%.
Also, TEP pays a commitment fee of 0.50% on the unused portion of the revolving
credit facility.
In January 2004, TEP borrowed $20 million under its revolving credit
facility and repaid it within 30 days. At June 30, 2004, there were no
outstanding borrowings under the revolving credit facility.
CONTRACTUAL OBLIGATIONS
There have been no significant changes in TEP's contractual obligations
or other commercial commitments from those reported in our 2003 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, including a covenant that requires
TEP to maintain a minimum level of net worth. As of June 30, 2004, the required
minimum net worth was $352 million. TEP's actual net worth at June 30, 2004, was
$422 million. As of June 30, 2004, TEP was in compliance with the terms of the
Credit Agreement.
TEP paid a $7 million dividend in June 2004. UniSource Energy is the
primary holder of TEP's common stock.
The Citizens Settlement Agreement, as approved by the ACC, states that
TEP may not pay dividends to UniSource Energy in excess of 75% of its earnings
until TEP's common equity equals 40% of total capitalization (excluding capital
lease obligations). As of June 30, 2004, TEP's common equity equaled 27% of
total capitalization (excluding capital lease obligations).
In addition to these limitations, the Federal Power Act states that
dividends shall not be paid out of funds properly included in the capital
account. 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.
UNISOURCE ENERGY SERVICES
RESULTS OF OPERATIONS
- ---------------------
UES' net income for the second quarter of 2004 was less than $1
million. 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. We
also expect operations at UNS Gas to vary with the seasons, with peak energy
usage occurring in the winter months. In the first six months of 2004, UES' net
income was $5 million.
49
UNS Electric
Second Quarter 2004 Results
On June 30, 2004, UNS Electric had 83,376 retail customers, a 1%
increase from March 31, 2004. The table below shows UNS Electric's kWh sales and
revenues for the three months ended June 30, 2004.
<table>
Sales Operating Revenue
- -------------------------------------------------------------------------------------
Three Months Ended June 30, 2004 2004
- -------------------------------------------------------------------------------------
-Millions of kWh- -Millions of Dollars-
Electric Retail Sales:
Residential 140 $15
Commercial 159 16
Industrial 58 4
Other 1 -
- -------------------------------------------------------------------------------------
Total Electric Retail Sales 358 $35
=====================================================================================
</table>
UNS Electric's utility gross margin (electric revenues less purchased
energy expense) was $11 million in the second quarter of 2004. Purchased energy
expense was $24 million in the second quarter of 2004. UNS Electric purchases
all of its energy requirements under a fixed price contract with Pinnacle West
Capital Corporation (PWCC), thus purchased energy expense is a function of kWh
sales volumes. Other O&M expenses were $5 million for the period. UNS Electric's
contribution to UES' net income was $2 million for the second quarter of 2004.
<table>
Year-to-date June 30, 2004 Results
Sales Operating Revenue
- -------------------------------------------------------------------------------------
Six Months Ended June 30, 2004 2004
- -------------------------------------------------------------------------------------
-Millions of kWh- -Millions of Dollars-
Electric Retail Sales:
Residential 292 $30
Commercial 280 29
Industrial 101 7
Other 2 -
- -------------------------------------- ------------------ ------- -------------------
Total Electric Retail Sales 675 $66
====================================== ================== ======= ===================
</table>
UNS Electric's utility gross margin (electric revenues less purchased
energy expense) was $22 million for the first six months of 2004. Purchased
energy expense was $44 million and other O&M expenses were $11 million, for the
period. UNS Electric's contribution to UES' net income was $2 million for the
first six months of 2004.
UNS Gas
Second Quarter 2004 Results
On June 30, 2004, UNS Gas had 130,413 retail customers, a 1% increase
from March 31, 2004. The table below shows UNS Gas' therm sales and revenues for
the three months ended June 30, 2004.
50
<table>
Sales Operating Revenue
- --------------------------------------- ------------------------ ------- ------------------------
Three Months Ended June 30, 2004 2004
- --------------------------------------- ------------------------ ------- ------------------------
-Millions of therms- -Millions of Dollars-
Retail Therm Sales:
Residential 8 $11
Commercial 4 4
Industrial 1 1
Public Authority 1 1
- --------------------------------------- ------------------------ ------- ------------------------
Total Retail Therm Sales 14 17
Transport - 1
Negotiated Sales Program (NSP) 4 2
- --------------------------------------- ------------------------ ------- ------------------------
Total Therm Sales 18 $20
======================================= ======================== ======= ========================
</table>
UNS Gas' utility gross margin (gas revenues less purchased energy
expense) was $9 million in the second quarter of 2004. Purchased energy expense
was $12 million in the first three months of 2004. UNS Gas purchases all of its
gas requirements under a supply and management agreement with BP Energy Company,
thus purchased energy expense is a function of therm sales volumes and the price
of natural gas. Other O&M expenses were $7 million for the period. UNS Gas
reported a net loss of $1 million for the second quarter of 2004. See Factors
Affecting Results of Operations, Rates and Regulations, Purchased Gas Adjustor,
below.
<table>
Year-to-date June 30, 2004 Results
Sales Operating Revenue
- --------------------------------------- ------------------------ ------- ------------------------
Six Months Ended June 30, 2004 2004
- --------------------------------------- ------------------------ ------- ------------------------
-Millions of therms- -Millions of Dollars-
Retail Therm Sales:
Residential 39 $43
Commercial 15 14
Industrial 2 1
Public Authority 4 4
- --------------------------------------- ------------------------ ------- ------------------------
Total Retail Therm Sales 60 62
Transport - 1
Negotiated Sales Program (NSP) 11 6
- --------------------------------------- ------------------------ ------- ------------------------
Total Therm Sales 71 $69
======================================= ======================== ======= ========================
</table>
UNS Gas' utility gross margin (gas revenues less purchased energy
expense) was $29 million in the first six months of 2004. Purchased energy
expense was $41 million and other O&M expenses were $15 million, for the period.
UNS Gas' contribution to UES' net income was $3 million for the first six months
of 2004.
FACTORS AFFECTING RESULTS OF OPERATIONS
- ---------------------------------------
COMPETITION
As required by the ACC Decision approving UniSource Energy's
acquisition of the Citizens Arizona gas and electric assets, on November 3,
2003, UNS Electric filed with the ACC an application for approval of 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
51
customers that choose competitive retail access, as well as Direct Access and
Settlement Fee schedules. UNS Electric 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, TEP -
Factors Affecting Results of Operations, Competition, above.
RATES AND REGULATION
Purchased Gas Adjustor
UNS Gas' retail rates include a Purchased Gas Adjustor (PGA) mechanism
intended to address the volatility of natural gas prices and allows UNS Gas to
recover its costs through a price adjuster. The difference between the actual
cost of UNS Gas' gas supplies and transportation contracts and the base cost of
gas approved by the ACC are deferred and recovered or repaid through the PGA
mechanism. The PGA charge changes 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. 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.
Purchased Power and Fuel Adjustor Clause
UNS Electric's retail rates include a Purchased Power and Fuel Adjustor
Clause (PPFAC), which allows for a separate surcharge or surcredit to the base
rate for delivered purchased power and fuel to collect or return under or over
recovery of costs.
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
UES' capital requirements consist primarily of capital expenditures.
UES' forecast for capital expenditures for the year ending December 31, 2004 is
approximately $37 million. UES intends to obtain, or have made available to them
through UniSource Energy, a revolving credit facility to use for working capital
purposes. This facility is expected to be in place within the next five months.
UNS Gas relies on the PGA mechanism included in its retail rates to
recover its cost of natural gas. Since the price of natural gas continues to
remain at historically high levels, UNS Gas' internal cash flows may not be
sufficient in the short-term to fund all of its operating and capital
expenditures. As a result, UNS Gas may need to borrow on a short-term basis
during the winter heating season of 2004-2005.
UNS Electric expects to generate sufficient internal cash flows to fund
its operating activities and construction expenditures during 2004.
Private Placement Notes
On August 11, 2003, UNS Gas and UNS Electric issued a total of $160
million of aggregate principal amount of senior unsecured notes in a private
placement.
The note purchase agreements for both UNS Gas and UNS Electric contain
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 agreements for both UNS Gas and 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,
UNS Gas, and UNS Electric at June 30, 2004.
52
<table>
Required Actual
Company Net Worth Net Worth
- ------------------- ----------------- -----------------
-Millions of Dollars-
UES $50 $95
UNS Gas 43 57
UNS Electric 26 39
- ------------------- ----------------- -----------------
</table>
CONTRACTUAL OBLIGATIONS
There have been no significant changes in UES' contractual obligations
or other commercial commitments from those reported in our 2003 Annual Report on
Form 10-K.
DIVIDENDS ON COMMON STOCK
The Citizens Settlement Agreement, as approved by the ACC, limits
dividends payable by UNS Gas and UNS Electric to 75% of earnings until the ratio
of common equity to total capitalization reaches 40%. At June 30, 2004, the
ratio of common equity to total capitalization for UNS Gas was 36% and for UNS
Electric was 39%.
The note purchase agreements for both UNS Gas and UNS Electric contain
restrictive covenants including restrictions on dividends. According to the note
purchase agreements, neither UNS Gas, nor UNS Electric, may declare or make
distributions or dividends (restricted payments) on their common stock unless,
(a) immediately after giving effect to such action no default or event of
default would exist under such company's note purchase agreement and (b)
immediately after giving effect to such action, such company would be permitted
to incur an additional dollar of indebtedness under the debt incurrence test for
such company.
MILLENNIUM ENERGY HOLDINGS, INC.
RESULTS OF OPERATIONS
Through affiliates, Millennium holds investments in unregulated energy
and emerging technology companies. At June 30, 2004, Millennium's assets
represented 5% of UniSource Energy's total assets. 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 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.
Millennium's consolidated net loss was $3 million for the three months
ended June 30, 2004 compared with a net loss of $4 million for the three months
ended June 30, 2003. The $1 million decrease in net losses is primarily due to:
o a decrease in net losses of $2 million from development and
manufacturing costs of Global Solar's photovoltaic products;
o income of less than $1 million related to a favorable overhead
billing rate adjustment at MicroSat Systems, Inc. (MicroSat),
which Millennium recorded in the second quarter of 2004, and
decreased operating losses at MicroSat; partially offset by:
- - a loss of $1 million, after tax, related to Millennium's investment
in Haddington; and
- - a net loss of less than $1 million, after tax, at Nations Energy
Corporation (Nations Energy) due to the write-off of an investment.
Millennium's consolidated net loss was $1 million for the six months
ended June 30, 2004 compared with a
53
net loss of $9 million for the six months ended June 30, 2003. The $8 million
decrease in net losses is primarily due to:
o a decrease in net losses of $3 million from development and
manufacturing costs of Global Solar's photovoltaic products;
o income of $2 million, after tax, related to Millennium's investment in
Haddington;
o $1 million of after-tax income related to certain revenues at MicroSat,
recorded in the first quarter of 2004 pursuant to a settlement of a
cost share agreement under a U.S. government contract;
o income of less than $1 million related to a favorable overhead
billing rate adjustment at MicroSat, which Millennium recorded in
the second quarter of 2004, and decreased operating losses at
MicroSat;
o decreased net losses of less than $1 million each from Other Millennium
Investments, including POWERTRUSION International, Inc., Southwest
Energy Solutions, Inc. and MEG;
o a decrease in net losses of less than $1 million due to no longer
having investments in ITN Energy Systems, Inc. (ITN) and TruePricing
Inc.;
o partially offset by a net loss of less than $1 million, after tax, at
Nations Energy due to the write-off of an investment.
The table below provides a breakdown of the net income and losses
recorded by Millennium. These results exclude sales and related costs to TEP.
<table>
Three Months Ended Six Months Ended
June 30, June 30,
2004 2003 2004 2003
- ------------------------------------------------------------------------------------------------------------------------------------
-Millions of Dollars-
Technology Investments
Global Solar and IPS
Research and Development Contract Revenues from Third Parties $ 0.1 $ 0.7 $ 0.3 $ 1.0
Other Revenues from Third Parties 0.5 0.3 1.4 0.4
Research and Development Contract Expenses and Losses (0.7) (1.2) (1.6) (2.6)
Research and Development - Internal Development Expenses (0.3) (0.7) (0.6) (1.1)
Depreciation and Amortization Expense (0.9) (0.9) (1.7) (1.6)
Administrative and Other Costs (1.8) (4.0) (3.3) (6.2)
Income Tax Benefits 1.2 2.3 2.2 4.0
- ------------------------------------------------------------------------------------------------------------------------------------
Global Solar and IPS Net Loss (1.9) (3.5) (3.3) (6.1)
MicroSat Net Income (Loss) 0.5 (0.4) 1.4 (0.7)
ITN Net Income (Loss) - 0.1 - (0.3)
- ------------------------------------------------------------------------------------------------------------------------------------
Total Technology Investments Net Loss (1.4) (3.8) (1.9) (7.1)
Other Millennium Investments Net Income (Loss) (1.9) (0.6) 0.7 (2.3)
- ------------------------------------------------------------------------------------------------------------------------------------
Total Millennium Net Loss $ (3.3) $ (4.4) $ (1.2) $ (9.4)
====================================================================================================================================
</table>
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
Under the acquisition agreement described in Overview of Consolidated
Businesses - Agreement and Plan of Merger above, UniSource Energy is limited as
to the amount it can invest in Millennium in the future. Consequently,
Millennium's ability to provide future funding for the operations of emerging
companies could be affected.
54
Technology Investments
During the first six months of 2004, Millennium made no contributions
to Global Solar. However, UniSource Energy provided $4 million to Global Solar
under a tax sharing agreement. Millennium has no remaining funding commitments
to Global Solar, other than the tax sharing agreement with UniSource Energy.
Millennium's debt commitment to IPS was $0.5 million at December 31,
2003, which Millennium funded during the first quarter of 2004. Dow Corning
Enterprises, Inc. (DCEI) made no additional contributions to IPS during the same
time period. In April 2004, Millennium and DCEI committed to loan up to an
additional $1 million each to IPS, and each funded $0.5 million of the
commitment at that time. DCEI funded its remaining $0.5 million commitment
during the second quarter of 2004, while Millennium funded its remaining $0.5
million commitment in July 2004. Millennium has no further funding commitments
to IPS. Pursuant to the terms of the 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, we would recognize a
loss of approximately $4 million.
Millennium made no contributions to MicroSat during the first six
months of 2004 and has no further funding commitments to MicroSat.
As technology developers, these entities face many challenges, such as
developing technologies that can be manufactured on an economic scale,
technological obsolescence, competitors and possible reductions in government
spending to advance technological research and development activities.
Other Millennium Investments
Millennium committed $15 million in capital, excluding fees, to
Haddington, a limited partnership which funds energy-related investments. A
member of the UniSource Energy Board of Directors has an investment in
Haddington and is a managing director of the general partner of the limited
partnership. At June 30, 2004, Millennium had funded $9 million of this
commitment, $0.2 million of which was funded during the first six months of
2004. Millennium expects the balance to be funded over the next three years. In
March 2004, Haddington sold one of its investments and recognized the related
gain as income. In April 2004, Millennium received a $7 million distribution
from Haddington related to the sale. In June 2004, Haddington wrote off another
of its investments and recognized the related loss. Millennium's share of the
loss was $2 million, before tax. Millennium recorded its share of Haddington's
income and loss during the first six months of 2004, which includes Haddington's
gains and losses on investments.
Millennium committed $6 million, including fees, to Valley Ventures
III, LP (Valley Ventures), a venture capital fund that invests in information
technology, microelectronics and biotechnology, primarily within the
southwestern U.S. Another member of the UniSource Energy Board of Directors is a
general partner of the company that manages the fund. As of June 30, 2004,
Millennium had funded $2 million of this commitment, $0.6 million of which was
funded during the first six months of 2004. Millennium expects the balance to be
funded by the end of 2007.
Nations Energy is wholly owned by Millennium. Through subsidiaries,
Nations Energy has a 32% interest in a 43 MW power plant in Panama. Although
Nations Energy still intends to sell its interest in this plant, the $0.8
million book value of the investment was written off in June 2004 because
attempts to sell the asset to date have been unsuccessful.
Millennium Commitments
Millennium's funding levels and share ownership in its investments are
subject to change in the future. Millennium's outstanding equity commitments are
currently limited to $6 million to Haddington and $4 million to Valley Ventures.
Millennium has no remaining debt commitments after the $0.5 million payment to
IPS in July 2004. Millennium may commit to provide additional funding to its
investments in the future.
55
Global Solar had commitments totaling $1 million at June 30, 2004 and
December 31, 2003 to incur future expenses relating to government contracts.
DIVIDENDS ON COMMON STOCK
Millennium did not pay any dividends to UniSource Energy in 2003 or the
first six months of 2004.
CRITICAL ACCOUNTING POLICIES
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 Policies 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 Policies
below. Other significant accounting policies and recently issued accounting
standards are discussed in the 2003 Annual Report on Form 10-K, Note 1 of Notes
to Consolidated Financial Statements - Nature of Operations and Summary of
Significant Accounting Policies.
ACCOUNTING FOR RATE REGULATION
TEP and UES 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's and UES' retail rates, the ACC may
not allow TEP or UES 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 and UES
are allowed to charge their customers. TEP and UES 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 the 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 regulatory assets, net of regulatory liabilities, totaled $259
million at June 30, 2004. Regulatory assets of $22 million are not presently
included in rate base and consequently are not earning a return on investment.
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 June 30, 2004, if
TEP had stopped applying FAS 71 to its remaining regulated operations, it would
have recorded an extraordinary after-tax loss of $157 million. While regulatory
orders and
56
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.
UES
UES' regulatory liabilities, net of regulatory assets, totaled $5
million at June 30, 2004. If UES stopped applying FAS 71 to its 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 liability balances, net of regulatory assets, at June
30, 2004, if UES had stopped applying FAS 71 to its regulated operations, it
would have recorded an extraordinary after-tax gain of $3 million. UES' 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.
ACCOUNTING FOR ASSET RETIREMENT OBLIGATIONS
TEP has identified legal obligations to retire generation plant assets
specified in land leases for its jointly-owned Navajo and Four Corners
Generating Stations. TEP also has certain environmental obligations at the San
Juan Generating Station. TEP has estimated that its share of these obligations
will be approximately $38 million at the date of retirement. As of June 30, 2004
and December 31, 2003, TEP had accrued $1 million for the decommissioning of its
generating facilities. This amount is recorded as an accrued asset retirement
obligation on the UniSource Energy and TEP balance sheets.
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. A
final retirement occurs when an entire transmission or distribution line is
permanently removed from service. Interim retirements occur as components of the
system are replaced. As a result, TEP is not recognizing the costs of final
removal of the transmission and distribution lines in the financial statements.
As of June 30, 2004 and December 31, 2003, TEP had accrued $64 million and $60
million for the net cost of removal for the interim retirements from its
transmission, distribution and general plant. The amount is shown as a
regulatory liability.
Upon adoption of FAS 143 on January 1, 2003, TEP recorded an asset
retirement obligation of $38 million at its net present value of $1 million,
increased depreciable assets by $0.1 million for asset retirement costs,
reversed $113 million of costs previously accrued for final removal from
accumulated depreciation, reversed previously recorded deferred tax assets by
$44 million and recognized the cumulative effect of accounting change as a gain
of $112 million ($67 million net of tax).
UES, MILLENNIUM AND UED
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. A
final retirement occurs when an entire transmission or distribution line is
permanently removed from service. Interim retirements occur as components of the
system are replaced. As a result, UES is not recognizing the cost of final
removal of the transmission and distribution lines in the financial statements.
As of June 30, 2004 and December 31, 2003, UES had accrued $1 million for the
net cost of removal for interim retirements from its transmission, distribution
and general plant. The amount is shown as a regulatory liability.
Millennium and UED have no asset retirement obligations.
TEP - PAYMENT DEFAULTS AND ALLOWANCES FOR DOUBTFUL ACCOUNTS
We record an allowance for doubtful accounts when we determine that an
account receivable will not be collected. As a result of payment defaults made
by market participants in California, TEP's collection shortfall from the CPX
and CISO was approximately $9 million for sales made in 2000 and $7 million for
sales made in 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 addressing 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
57
the CISO by $3 million in the second quarter of 2004 by recording a reduction of
wholesale revenue. The amount that TEP ultimately collects would have an impact
on earnings if the amount received is more or less than the $3 million TEP has
on its balance sheet. If TEP collects all of the $16 million, pre-tax income
will increase by $13 million. If TEP does not collect any of the $16 million,
pre-tax income will decrease by $3 million. In addition, TEP has cash collateral
of approximately $1 million on deposit in an escrow account with the CPX, which
is currently unavailable to TEP due to the CPX's bankruptcy stay.
TEP's reserve for electric wholesale accounts receivable on its balance
sheet was approximately $13 million at June 30, 2004 and $10 million at December
31, 2003.
PENSION AND OTHER POSTRETIREMENT 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
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 using a rate of
6.25% at December 31, 2003, compared with 6.75% at December 31, 2002. TEP
discounted its other postretirement plan obligations using a rate of 5.5% at
December 31, 2003, compared with 6.75% at December 31, 2002. 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 and are expected to be available during the
period to maturity of the pension benefits. In selecting the appropriate rate,
TEP also considers the durations of plan obligations.
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 2004 by approximately
$1 million. A similar increase in the discount rate would decrease the ABO by
approximately $4 million and the related plan expense for 2004 by approximately
$1 million. For TEP's other postretirement benefits plan, 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 2004.
TEP calculates the market-related value of plan assets using the fair
value of plan assets on the measurement date. At December 31, 2003 and 2002, TEP
assumed its plans' assets would generate a long-term rate of return of 8.75%. 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 2004.
58
TEP recorded a minimum pension liability of approximately $4 million at
December 31, 2003, compared with $7 million at December 31, 2002. Improved stock
market conditions offset a further reduction in the assumed discount rate.
Based on the above assumptions, TEP will record pension expense of
approximately $8 million and other postretirement benefit expense of $6 million
ratably throughout 2004. TEP will make required pension plan contributions of $5
million in 2004. 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 2004.
TEP increased the initial health care cost trend rate used in valuing
its postretirement benefit obligation to 12.1% at December 31, 2003. 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 $5 million and the related plan expense by less than
$1 million.
UES
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 of its employees. UES did not assume the pension obligation
for employees' years of service with Citizens. UES performed an actuarial
valuation, as of the date of acquisition, to determine its pension expense for
the balance of 2003. A discount rate of 6.5% was assumed based on rates
available at that date and the duration of plan obligations.
UES discounted its future pension plan obligations using a rate of
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 of approximately $1
million at December 31, 2003. UES will record pension expense of $1 million in
2004. The pension plan is not yet funded but all required contributions will be
made in accordance with minimum funding standards. UES will make a pension plan
contribution of $1 million in 2004.
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 obligation has been recorded at a discounted value
of $2 million using a discount rate of 5.25%. The plan is not funded. UES does
not expect postretirement medical benefit expenses to have a material impact on
its operations.
ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND TRADING ACTIVITIES
A derivative financial instrument or other contract derives its value
from another investment or designated benchmark. TEP's, UES' and MEG's
derivative activities are described fully in UniSource Energy and TEP's 2003
Annual Report on Form 10-K.
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 the first six months of 2004, 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 will expire during the
summer months of 2004 through 2006, 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.
59
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.
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 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.
The market prices used to determine fair values for TEP's and MEG's
derivative instruments are estimated based on various factors including broker
quotes, exchange prices, over the counter prices and time value.
TEP's and MEG's derivative activities are reported as follows:
o TEP's net unrealized and realized gains and losses on forward sales
contracts are components of Electric Wholesale Sales;
o TEP's net unrealized and realized gains and losses on forward purchase
contracts are components of Purchased Power;
o TEP's net unrealized gains and losses on commodity price swaps are
included in Other Comprehensive Income, which is a component of
Common Stock Equity;
o TEP's net realized gains and losses on commodity price swaps are
reclassified out of Other Comprehensive Income into Fuel expense;
and
o MEG's net unrealized and realized gains and losses on trading
activities are components of 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 unrealized gains and losses from TEP's forward
contracts were less than $1 million for each of the three-month periods ended
June 30, 2004 and 2003 and less than $1 million for each of the six-month
periods ended June 30, 2004 and 2003. The net pre-tax realized and unrealized
gains and losses from MEG's trading activities were also less than $1 million
for each of the three-month periods ended June 30, 2004 and 2003 and less than
$1 million for each of the six-month periods ended June 30, 2004 and 2003. The
net pre-tax unrealized gains and losses from TEP's commodity swap agreements
recorded as cash flow hedges and included in Other Comprehensive Income were $2
million as of June 30, 2004. The net pre-tax realized gains and losses from
TEP's commodity swap agreements that were reclassified out of Other
Comprehensive Income were less than $1 million for each of the three and six
month periods ended June 30, 2004. TEP had no material cash flow hedges at
December 31, 2003.
TEP's commodity swap agreements currently satisfy the requirements for
cash flow hedge accounting and are considered to be highly effective in
offsetting changes in the fair market value of the gas contracts being hedged.
The cash flow hedges are being assessed on an ongoing basis to ensure they
continue to qualify for hedge accounting. If the hedges become ineffective in
the future, the amounts included in Other Comprehensive Income will be reversed
and recorded as unrealized gains and losses in the income statement.
TEP's derivative assets and liabilities are reported in Other Current
Assets and Other Current Liabilities on TEP and UniSource Energy's balance
sheets. The fair value of TEP's derivative assets was $2 million at June 30,
2004 and the fair value of TEP's derivative liabilities was less than $1 million
at December 31, 2003. MEG's trading assets and liabilities are reported in
Trading Assets and Trading Liabilities on UniSource Energy's balance sheet. The
fair value of MEG's trading assets, including its Emissions Allowance inventory,
was $63 million at June 30, 2004 and $22 million at December 31, 2003. The fair
value of MEG's trading liabilities was $60 million at June 30, 2004 and $19
million at December 31, 2003.
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 June 30, 2004, less than $1 million in sales were netted against
less than $1 million in purchases, resulting in a small net gain. For the six
months ended June 30, 2004, $2 million in sales were netted against $2 million
in purchases, resulting in a small net gain.
See Market Risks - Commodity Price Risk in Item 3.
60
PLANT ASSET DEPRECIABLE LIVES - TEP AND UES
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 both UES and TEP have been approved by the ACC in
prior rate decisions. Depreciation rates for transmission and distribution
cannot be changed without ACC approval. We are currently reviewing the estimated
useful lives of all our assets due to a variety of factors including the
construction of Springerville Unit 3 and the related environmental upgrades
being made to Springerville Unit 2, new information received from the operators
of the remote generating stations, and information received in connection with
an analysis of FAS 143 retirement obligations.
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 the first six
months of 2004, depreciation expense related to generation assets was $19
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, the Company engaged an independent
third party to review the economic estimated useful lives of TEP's owned
generating assets in Springerville, Arizona. The Company then hired a different
independent third party to perform a depreciation study for the generation
assets owned by TEP, taking into 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 will
lengthen the useful lives of various generation assets for periods ranging from
11 to 22 years, beginning in July 2004. The expected annual impact of these
changes in depreciation rates is a reduction in depreciation expense of $8
million, or $4 million during the remaining six months of calendar year 2004. 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 twenty
years, TEP's annual depreciation expense would decrease by an additional $6
million.
CHANGE IN UNBILLED REVENUE ESTIMATION METHODOLOGY - TEP
TEP's and UES' 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 judgement including
estimates of retail sales and customer usage patterns. The unbilled revenue is
estimated by comparing the actual MWhs/therms delivered to the MWhs/therms
billed to TEP and UES retail customers. The excess of MWhs/therms delivered over
MWhs/therms billed is then allocated to the retail customer classes based on
estimated usage by each customer class. TEP and UES 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 months and decreases during the fall months. The
unbilled revenue amount for UES gas sales increases during the fall and winter
months and decreases during the spring and summer months, whereas, the unbilled
revenue amount for UES electric sales increases during the spring and summer
months and decreases during the fall and winter months.
During the second quarter of 2004, we determined that the kWh
information used to estimate kWhs delivered to customers was generally
understated. Additionally, we determined that TEP's then existing method of
pricing computed unbilled kWh sales quantities among customer classes was
weighting usage by lower-priced customers too heavily and weighting usage by
higher-priced customers too lightly. For TEP, the price paid by customers varies
from a low of 3.7 cents per kWh for interruptable industrial load to a high of
13 cents per kWh for small commercial customers, so that allocations among
customer classes are a significant element of unbilled revenues. Effective with
the second quarter of 2004, we changed the estimation methodology used to
quantify unbilled kWh sales and price the computed unbilled kWh sales quantities
to more accurately reflect actual usage and restated prior periods.
61
Under the revised estimation methodology, unbilled sales are estimated
for the month by reviewing the meter reading schedule and determining the number
of billed and unbilled kWhs for each cycle. Current month unbilled kWhs are
allocated by customer class. New unbilled revenue amounts are recorded and
unbilled revenue estimates from the prior month are reversed. The primary
difference between the prior estimation methodology and the current methodology
results from the reversal of the prior month's accrued unbilled revenue rather
than a methodology that had the effect of reversing unbilled kWhs, and a more
precise application of the current rates by customer class to kWhs unbilled at
the end of each month.
DEFERRED TAX VALUATION
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 June 30, 2004 and December 31, 2003, UniSource Energy and the
Millennium entities had a valuation allowance of $10 million and $9 million,
respectively relating to net operating 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 $10 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 valuation
allowance relates to investment tax credit carryforwards at TEP, which may not
be able to be used on tax returns prior to their expiration.
In the future, if UniSource Energy and TEP determine that it is
probable that TEP will not be able to use all or a portion of its net operating
loss and and more of its investment tax credit carryforward amounts, then
UniSource Energy and TEP would record additional valuation allowance and
recognize tax expense. Factors that could cause TEP to record a valuation
allowance would be a change in expected future taxable income or a change in tax
filing status due to the proposed acquisition. See Outlook and Strategies -
Agreement and Plan of Merger, above.
NEW ACCOUNTING PRONOUNCEMENTS
The FASB recently issued the following Statements of Financial
Accounting Standards (FAS) and FASB Interpretations (FIN):
o FIN 46, Consolidation of Variable Interest Entities, was issued in
January 2003, and was subsequently revised in December 2003 (FIN 46R).
The primary objectives of FIN 46R are to provide guidance on the
identification of entities for which control is achieved through means
other than through voting rights (variable interest entities) and to
determine when and which business enterprises should consolidate the
variable interest entity (primary beneficiary). FIN 46R requires that
both the primary beneficiary and all other enterprises with a
significant variable interest make additional disclosures. For public
companies, the revised FIN 46R is effective for financial periods
ending after March 15, 2004. The adoption of FIN 46R did not have a
significant impact on our financial statements.
o FAS 132, Employers' Disclosures about Pensions and Other
Postretirement Benefits (revised 2003), was issued by the FASB in
December 2003. FAS 132 requires additional disclosures about the
assets, obligations, cash flows, and net periodic benefit cost of
defined benefit pension plans and other defined benefit postretirement
plans beyond those in the original Statement 132 which it replaces. FAS
132, as revised, is effective for fiscal years ending after December
15, 2003. The revised disclosure requirements are included in Note 12
of Notes to Consolidated Financial Statements.
FASB Staff Position No. FAS 106-2 (FSP 106-2), Accounting and
Disclosure Requirements Related to the Medicare Prescription Drug, Improvement
and Modernization Act of 2003, provides guidance related to accounting for the
federal subsidy available to employers providing retirees with prescription drug
benefits that are at least actuarially equivalent to Medicare Part D. For public
companies, FSP 106-2 is effective for the first interim or annual period
beginning after June 15, 2004. FASB Statement No. 106, Employers' Accounting for
Postretirement Benefits Other Than Pensions, requires presently enacted changes
in relevant laws to be considered in current
62
period measurements of postretirement benefit costs and the Accumulated
Projected Benefit Obligation. Prescription drug benefits are available to a
limited number of UniSource Energy retirees who are Medicare eligible. However,
the Accumulated Projected Benefit Obligation or net periodic postretirement
benefit cost do not reflect any amount associated with the subsidy because at
this time we are unable to determine whether this drug coverage is comparable
(actuarial equivalent) or more generous than Medicare Part D. The effects of the
Medicare Prescription Drug, Improvement, and Modernization Act of 2003 will be
incorporated in our next measurement of plan asset and obligations. The adoption
of FSP 106-2 is not expected to have a significant impact on our postretirement
benefit costs or cash flows.
In August 2003, the Emerging Issues Task Force (EITF) published Issue
No. 03-11, Reporting Realized Gains and Losses on Derivative Instruments That
Are Subject to FASB Statement No. 133, Accounting for Derivative Instruments and
Hedging Activities, and Not "Held for Trading Purposes" as Defined in EITF Issue
No. 02-3 (EITF 03-11). EITF 03-11 discusses whether realized gains and losses
should be shown gross or net in the income statement for contracts that are not
held for trading purposes, as defined in EITF 02-3, but are derivatives subject
to FAS 133. Determining whether realized gains and losses on derivative
contracts not held for trading purposes should be reported in the income
statement on a gross or net basis is a matter of judgment that depends on the
relevant facts and circumstances with respect to the various activities of the
entity. Retroactive application of EITF 03-11 is not required. Beginning January
1, 2004, the realized gains and losses on derivative instruments that are not
held for trading purposes but are eventually net settled are shown net in the
income statement. The impact of adopting EITF 03-11 was immaterial as of June
30, 2004.
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,
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.
63
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 UniSource
Energy's unregulated businesses.
12. Ability to successfully integrate UES' businesses and achieve
expected earnings.
13. Unanticipated changes in future liabilities relating to employee
benefit plans due to changes in market values of its retirement
plan assets and health care costs.
14. The outcome of any ongoing litigation.
15. 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.
16. Ability to develop and operate Springerville Generating Station
Unit 3 and achieve expected cost savings.
17. Ability to obtain necessary approvals and satisfy the other
closing conditions contained in the acquisition agreement, so that
the acquisition of UniSource Energy by an affiliate of Saguaro
Utility can occur in a timely manner.
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, 2003, 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 2003 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 of
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
energy procurement activities at TEP and UES. Our Risk Management Committee
consists of officers from the finance, accounting, legal, wholesale marketing,
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
64
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 on a quarterly basis and as needed.
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 energy 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 energy and natural gas purchases during
its summer peaking period to ensure it can meet its load and reserve
requirements and account for other contract 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 dictate that TEP can 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.
The majority of TEP's forward contracts are considered to be "normal
purchases and sales" of energy and are not considered to be derivatives under
Statement of Financial Accounting Standards No. 133, Accounting for Derivative
Instruments and Hedging Activities (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 using actively quoted
prices obtained from brokers for the appropriate energy product. 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. The net
pre-tax unrealized gains and losses from TEP's forward electricity contracts
were less than $1 million for each of the three month periods ended June 30,
2004 and 2003. This demonstrates the limited derivative forward contract
activity conducted by TEP and the limited impact on TEP's operating results and
financial condition.
TEP has two purchased power agreements for the period 2003 through
2006. During the second quarter of 2004, TEP purchased approximately 32,000 MWh
under these contracts; energy purchased under these agreements is adjusted for
changes in the price of natural gas. In the first six months of 2004,
approximately 34,700 MWh were purchased under these contracts.
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 to meet the summer peak demands of its retail customers and to meet
local reliability needs. Due to its increasing seasonal gas usage, TEP hedges a
portion of its natural gas purchases with fixed price contracts for a maximum of
three years, and purchases its remaining gas needs in the spot and short-term
markets through its supplier Southwest Gas Corporation (SWG). The net pre-tax
unrealized gains and losses from TEP's commodity swap agreements recorded as
cash flow hedges and included in Other Comprehensive Income were $2 million as
of June 30, 2004. The net pre-tax realized gains and losses from TEP's commodity
swap agreements that were reclassified out of Other Comprehensive Income were
less than $1 million for each of the three and six months periods ended June 30,
2004.
In the first six months of 2004, the average price of natural gas was
$5.21 per MMBtu compared with $5.35 per MMBtu in the same period last year.
Natural gas prices remained high throughout 2003 and into 2004 with continued
demand, storage and production concerns. The increase in the regional supply of
gas-generated energy and the completion of a 500-kV transmission connection,
however, allowed TEP to decrease 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 110,000 MWh, or 2% of
total generation in the first six months of 2004, compared with approximately
194,000 MWh, or 4% of total generation in same period of 2003.
65
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. UNS Electric's retail rates include a PPFAC surcharge, which
allows for recovery of costs associated with the current full-requirements power
supply agreement with PWCC.
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
June 30, 2004 and December 31, 2003, the fair value of MEG's trading assets
combined with Emission Allowances it holds in escrow was $63 million and $22
million, respectively. The fair value of MEG's trading liabilities was $60
million at June 30, 2004 and $19 million at December 31, 2003. The significant
increase in the fair value of MEG's trading assets and liabilities at June 30,
2004 compared with December 31, 2003 is the result of an increase in the value
of SO2 allowances from $216 per allowance to $420 per allowance. During the
first six months of 2004, MEG reflected a $2 million unrealized gain and a $2
million realized loss on its income statement, compared with an unrealized gain
of $2 million and a realized loss of $2 million in the first six months of 2003.
<table>
Unrealized Gain (Loss) of MEG's Trading Activities
- Millions of Dollars -
------------------------------------------------------------------------------
Source of Fair Value Maturity Maturity Maturity over Total Unrealized
At June 30, 2004 0 - 6 mos. 6 - 12 mos. 1 yr. Gain (Loss)
------------------------------------------------------------------------------------------------------------------
Prices actively quoted $ (9) $ - $ - $ (9)
Prices based on models and other
valuation methods 7 3 2 12
------------------------------------------------------------------------------------------------------------------
Total $ (2) $ 3 $ 2 $ 3
==================================================================================================================
</table>
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.
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 June 30, 2004, TEP's total
credit exposure related to its wholesale marketing activities (excluding
defaulted amounts owed by the CPX and the CISO, was approximately $4 million and
MEG's total credit exposure related to its trading activities was $27 million.
TEP and MEG's credit exposure is diversified across approximately 23
counterparties. Approximately $6 million of TEP's exposure is to non-investment
grade companies.
66
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 receivable from Mirant Curacao. The
receivable 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 receivable. As of June 30, 2004, Nations Energy's
receivable from Mirant Curacao is approximately $8 million. The receivable 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 on June 30, 2004. The remaining payments are expected as follows: $4
million in July 2005 and $5 million in July 2006.
The receivable 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 remaining receivable and any applicable interest.
However, Nations Energy cannot predict the ultimate outcome that Mirant's
bankruptcy will have on the collectibility of the receivable from Mirant
Curacao. Nations Energy will continue to evaluate the collectibility of the
receivable, but currently expects to collect the receivable in its entirety and
has not recorded any reserve for this receivable.
ITEM 4. - CONTROLS AND PROCEDURES
- --------------------------------------------------------------------------------
Except as noted below with respect to unbilled revenues, 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 December 31, 2003. Based on
such evaluation, with the exception of the unbilled revenue matter discussed
below, 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.
There has been no change in UniSource Energy or TEP's internal control
over financial reporting that occurred during the most recent fiscal quarter
that has materially affected, or is reasonably likely to materially affect
UniSource Energy' or TEP's internal control over financial reporting except as
described below:
During the second quarter of 2004, we determined that we had a material
weakness in internal control over TEP's existing methodology of estimating
unbilled revenues. As a result, we restated the 2003 financial statements
included in this Form 10-K.
During the second quarter of 2004, we determined that the kWh
information used to estimate kWhs delivered to TEP's customers was, in general,
understated. Additionally, we determined that TEP's existing method of pricing
computed unbilled kWh sales quantities among customer classes was weighting
usage by lower-priced customers too heavily and weighting usage by higher-priced
customers too lightly. For TEP, the price paid by customers varies from a low of
3.7 cents per kWh for interruptible industrial load to a high of 13 cents per
kWh for small commercial customers, so that allocations among customer classes
are a significant element of unbilled revenues. Effective with the second
quarter of 2004, we changed the estimation methodology used to quantify unbilled
kWh sales and price the computed unbilled kWh sales quantities to more
accurately reflect actual usage and restated prior periods.
In addition to restating our financial statements, subsequent to the
date of our evaluation, we implemented changes to improve controls over
estimating unbilled revenue.
Also during the second quarter of 2004, we engaged an independent
consulting firm to test various aspects of our general information technology
controls primarily in the area of network access controls. The consultant made
several recommendations, which we implemented by the end of July 2004. While we
are aware of
67
no impacts to date on our financial reporting from not having had these
controls in place before, we believe these improvements to controls will enhance
data integrity controls subsequent to the date of our evaluation.
PART II - OTHER INFORMATION
ITEM 1. - LEGAL PROCEEDINGS
- --------------------------------------------------------------------------------
On June 7, 2004, the City of Tacoma, Washington filed a lawsuit (City
of Tacoma v. American Electric Power Service 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 in Item 3.
Legal Proceedings, Cross-Complaints in Wholesale Electricity Antitrust Cases I
and II, of our 2003 Annual Report on Form 10-K (the Wholesale Electricity
Antitrust Cases). TEP and the other defendants have filed a petition to have the
case transferred to the United States District Court for the Southern District
of California and consolidated with the Wholesale Electricity Antitrust Cases.
TEP believes these claims are without merit and intends to vigorously contest
them.
We discuss other legal proceedings in Note 9 of Notes to Condensed
Consolidated Financial Statements.
ITEM 4. - SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
- --------------------------------------------------------------------------------
UniSource Energy conducted its annual meeting of shareholders on May 7,
2004. At that meeting, the shareholders of UniSource Energy elected members of
the Board of Directors.
The total votes were as follows:
<table>
Nominee For Withheld
- ----------------------------------- -------------------- -----------------
Lawrence J. Aldrich 28,340,551 348,677
Larry W. Bickle 28,334,757 354,471
Elizabeth T. Bilby 27,729,406 959,822
Harold W. Burlingame 28,338,921 350,307
John L. Carter 28,263,410 425,818
Robert A. Elliott 27,893,563 795,665
Kenneth Handy 27,896,910 792,318
Warren Y. Jobe 27,738,751 950,477
James S. Pignatelli 28,321,330 367,898
- ----------------------------------- -------------------- -----------------
</table>
68
ITEM 5. - OTHER INFORMATION
- --------------------------------------------------------------------------------
ADDITIONAL FINANCIAL DATA
The following table reflects the ratio of earnings to fixed charges for
TEP:
<table>
6 Months Ended 12 Months Ended
(Restated) (1)
---------------------------- -----------------------
June 30, June 30,
2004 2004
Ratio of Earnings to Fixed Charges 1.46 1.67
<fn>
(1) See Note 1 of Notes to Condensed Consolidated Financial Statements
</fn>
</table>
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.
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.
<table>
Adjusted EBITDA and Net Cash Flows from Operating Activities
UniSource Energy
-------------------------------------------------------
Three Months Ended Six Months Ended
June 30, June 30,
2003 2003
2004 (Restated)(1) 2004 (Restated)(1)
- -----------------------------------------------------------------------------------------------------------
-Millions of Dollars -
Adjusted EBITDA $ 115 $ 94 $ 216 $ 145
Net Cash Flows from Operations $ 96 $ 34 $ 138 $ 44
- -----------------------------------------------------------------------------------------------------------
</table>
<table>
69
TEP
-------------------------------------------------------
Three Months Ended Six Months Ended
June 30, June 30,
2003 2003
2004 (Restated)(1) 2004 (Restated)(1)
- -----------------------------------------------------------------------------------------------------------
-Millions of Dollars -
Adjusted EBITDA $ 115 $ 104 $ 199 $ 166
Net Cash Flows from Operations $ 82 $ 42 $ 116 $ 63
- -----------------------------------------------------------------------------------------------------------
<fn>
(1) See Note 1 of Notes to Condensed Consolidated Financial Statements
</fn>
</table>
<table>
Reconciliation of Adjusted EBITDA to Cash Flows from Operations
UniSource Energy
-------------------------------------------------------
Three Months Ended Six Months Ended
June 30, June 30,
2003 2003
2004 (Restated)(1) 2004 (Restated)(1)
- -----------------------------------------------------------------------------------------------------------
-Millions of Dollars -
Adjusted EBITDA (2) $ 115 $ 94 $ 216 $ 145
Net Cash Flows from Operations
Less: Income Taxes 12 6 18 (3)
Less: Total Interest Expense 40 40 83 80
Changes in Assets and Liabilities and
Other Non-Cash Items 33 (14) 23 (24)
- -----------------------------------------------------------------------------------------------------------
Net Cash Flows from Operating Activities $ 96 $ 34 $ 138 $ 44
- -----------------------------------------------------------------------------------------------------------
<fn>
(1) See Note 1 of Notes to Condensed Consolidated Financial Statements
</fn>
</table>
<table>
TEP
-------------------------------------------------------
Three Months Ended Six Months Ended
June 30, June 30,
2003 2003
2004 (Restated)(1) 2004 (Restated)(1)
- -----------------------------------------------------------------------------------------------------------
-Millions of Dollars -
Adjusted EBITDA (2) $ 115 $ 104 $ 199 $ 166
Net Cash Flows from Operations
Less: Income Taxes 15 10 17 6
Less: Total Interest Expense 37 40 77 80
Changes in Assets and Liabilities and
Other Non-Cash Items 19 (12) 11 (17)
- -----------------------------------------------------------------------------------------------------------
Net Cash Flows from Operating Activities $ 82 $ 42 $ 116 $ 63
- -----------------------------------------------------------------------------------------------------------
<fn>
(1) See Note 1 of Notes to Condensed Consolidated Financial Statements
</fn>
</table>
70
<table>
(2) Adjusted EBITDA was calculated as follows:
UniSource Energy
----------------------------------------------------
Three Months Ended Six Months Ended
June 30, June 30,
2003 2003
2004 (Restated)(1) 2004 (Restated)(1)
- ----------------------------------------------------------------------------------------------------------------------------
-Millions of Dollars -
Net Income $ 13 $ 7 $ 19 $ 59
Amounts from the Income Statements:
Less: Cumulative Effect of Accounting Change - - - 67
Plus: Income Taxes 12 6 18 (3)
Plus: Total Interest Expense 40 40 83 80
Plus: Depreciation and Amortization 37 31 72 61
Plus: Amortization of Transition Recovery Asset 12 8 21 12
Plus: Depreciation included in Fuel and Other O&M Expense* 1 2 3 3
- ----------------------------------------------------------------------------------------------------------------------------
Adjusted EBITDA $ 115 $ 94 $ 216 $ 145
- ----------------------------------------------------------------------------------------------------------------------------
</table>
<table>
TEP
----------------------------------------------------
Three Months Ended Six Months Ended
June 30, June 30,
2003 2003
2004 (Restated)(1) 2004 (Restated)(1)
- ----------------------------------------------------------------------------------------------------------------------------
-Millions of Dollars -
Net Income $ 18 $ 14 $ 19 $ 73
Amounts from the Income Statements:
Less: Cumulative Effect of Accounting Change - - - 67
Plus: Income Taxes 15 10 17 6
Plus: Total Interest Expense 37 40 77 80
Plus: Depreciation and Amortization 32 30 62 59
Plus: Amortization of Transition Recovery Asset 12 8 21 12
Plus: Depreciation included in Fuel and Other O&M Expense* 1 2 3 3
- ----------------------------------------------------------------------------------------------------------------------------
Adjusted EBITDA $ 115 $ 104 $ 199 $ 166
- ----------------------------------------------------------------------------------------------------------------------------
<fn>
(1) See Note 1 of Notes to Condensed Consolidated Financial Statements
</fn>
</table>
*See Supplemental Cash Flow Information in Note 16 of Notes to the Consolidated
Financial Statements.
<table>
Net Debt and Total Debt and Capital Lease Obligations - TEP
As of As of
June 30, December 31,
2004 2003
------------------------------------
-Millions of Dollars-
Net Debt $ 1,731 $ 1,761
Total Debt and Capital Lease Obligations $ 1,906 $ 1,940
</table>
71
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 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. Net Debt should not be considered to be an
alternative to debt or any other items calculated in accordance with GAAP.
<table>
Reconciliation of Total Debt and Capital Lease Obligations to Net Debt
As of As of December
June 30, 31,
2004 2003
- -----------------------------------------------------------------------------------------------
-Millions of Dollars-
Long-Term Debt $ 1,125 $ 1,126
Current Portion - Long-Term Debt 2 2
- -----------------------------------------------------------------------------------------------
Total Debt 1,127 1,128
Capital Lease Obligations 725 762
Current Portion - Capital Lease Obligations 54 50
- -----------------------------------------------------------------------------------------------
Total Debt and Capital Lease Obligations 1,906 1,940
Investment in Lease Debt and Equity (175) (179)
- -----------------------------------------------------------------------------------------------
Net Debt $ 1,731 $ 1,761
- -----------------------------------------------------------------------------------------------
</table>
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 at the UniSource Energy main page.
Information contained at UniSource Energy's website is not part of any
report filed with, or furnished to, the SEC by UniSource Energy or TEP.
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 and 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 AND REPORTS ON FORM 8-K
- --------------------------------------------------------------------------------
(a) Exhibits.
- --------------------------------------------------------------------------------
See Exhibit Index.
(b) Reports on Form 8-K.
o UniSource Energy and TEP Form 8-K, dated June 1, 2004, furnished
pursuant to Item 5 "Other Events," describing TEP's general rate
case information filed with the ACC.
o UniSource Energy and TEP Form 8-K, dated August 5, 2004, furnished
pursuant to Item 12 "Disclosure of Results of Operations and
Financial Condition," announcing the delay of releasing
72
o UniSource Energy's financial results for the three- and six-months
periods ended June 30, 2004, and the potential delay in filing
UniSource Energy's and TEP's Form 10-Q for the quarterly period
ended June 30, 2004.
o UniSource Energy and TEP Form 8-K, dated August 24, 2004,
furnished pursuant to Item 2.02 "Disclosure of Results and
Financial Condition," announcing the release of UniSource Energy
and TEP's second quarter 2004 financial results.
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: August 24, 2004 /s/ Kevin P. Larson
-------------------------------------
Kevin P. Larson
Vice President and Principal
Financial Officer
TUCSON ELECTRIC POWER COMPANY
(Registrant)
Date: August 24, 2004 /s/ Kevin P. Larson
-------------------------------------
Kevin P. Larson
Vice President and Principal
Financial Officer
73
EXHIBIT INDEX
12 - 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 Act of
1934.
74