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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For The Quarterly Period Ended March 31, 2003
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 May 8, 2003, 33,589,114 shares of UniSource Energy Corporation's
Common Stock, no par value (the only class of Common Stock), were outstanding.
At May 8, 2003, 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.
- --------------------------------------------------------------------------------
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 Accountants............................................1
PART I - FINANCIAL INFORMATION
Item 1. - Financial Statements
UniSource Energy Corporation
Comparative Condensed Consolidated Statements of Income (Loss)..........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 (Loss)..........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 and Basis of Accounting Presentation.......10
Note 2. Regulatory Accounting...........................................10
Note 3. Asset Purchase Agreements.......................................11
Note 4. Accounting Change: Accounting for Asset Retirement Obligations..12
Note 5. Stock-Based Compensation........................................14
Note 6. Accounting for Derivative Instruments and Trading Activities....15
Note 7. Business Segments...............................................16
Note 8. Millennium......................................................17
Note 9. Commitments and Contingencies...................................18
Note 10. Wholesale Accounts Receivable and Allowances....................20
Note 11. UniSource Energy Earnings per Share (EPS).......................21
Note 12. Income and Other Taxes..........................................21
Note 13. New Accounting Pronouncements...................................22
Note 14. Review by Independent Accountants...............................22
Item 2. - Management's Discussion and Analysis of Financial Condition
and Results of Operations
Overview of Consolidated Business........................................23
Results of Operations
UniSource Energy Consolidated..........................................23
Contribution by Business Segment.......................................24
Results of TEP.........................................................24
Results of Millennium..................................................27
Results of UED.........................................................27
Citizens Acquisition.....................................................27
Springerville Generating Station Expansion...............................29
Factors Affecting Results of Operations
Competition............................................................29
Industry Restructuring.................................................30
Market Risks...........................................................32
Liquidity and Capital Resources
UniSource Energy - Consolidated Cash Flows.............................34
UniSource Energy - Parent Company......................................35
TEP - Electric Utility.................................................35
ii
TABLE OF CONTENTS
(concluded)
Millennium - Unregulated Businesses....................................37
UED - Unregulated Energy Business......................................38
Financing Risks........................................................38
Contractual Obligations................................................38
Guarantees and Indemnities.............................................39
Dividends on Common Stock..............................................39
Outlook and Strategies...................................................40
Critical Accounting Policies.............................................40
New Accounting Pronouncements............................................44
Safe Harbor for Forward-Looking Statements...............................45
Item 3. - Quantitative and Qualitative Disclosures about Market Risk......46
Item 4. - Controls and Procedures.........................................46
PART II - OTHER INFORMATION
Item 1. - Legal Proceedings...............................................47
Item 5. - Other Information
Additional Financial Data................................................48
Approval of Non-Audit Services...........................................48
SEC Reports Available on UniSource Energy's Website......................48
Item 6. - Exhibits and Reports on Form 8-K................................48
Signatures..................................................................49
Certifications Pursuant to Section 302 of the Sarbanes-Oxley Act............50
Exhibit Index...............................................................54
iii
DEFINITIONS
The abbreviations and acronyms used in the 2003 First Quarter Form 10-Q are
defined below:
- --------------------------------------------------------------------------------
ACC.......................... Arizona Corporation Commission.
ACC Holding Company Order.... The order approved by the ACC in November
1997 allowing TEP to form a holding company.
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.................. A proposed agreement with the ACC Staff
dated April 1, 2003, addressing rate case and
financing issues in the planned acquisition by
UniSource Energy of the Citizens' Arizona gas
and electric assets.
Common Stock................. UniSource Energy's common stock, without par
value.
CPX.......................... California Power Exchange.
Credit Agreement............. Credit Agreement between TEP and a syndicate of
banks, dated as of November 14, 2002.
Emission Allowance(s)........ An allowance issued by the Environmental
Protection Agency which permits emission of one
ton of sulfur dioxide. These allowances can be
bought and sold.
energy....................... The amount of power produced over a given
period of time; measured in MWh.
ESP.......................... Energy Service Provider.
FAS 71....................... Statement of Financial Accounting Standards No.
71: Accounting for the Effects of Certain Types
of Regulation.
FAS 133...................... Statement of Financial Accounting Standards No.
133: Accounting for Derivative Instruments and
Hedging Activities.
FAS 143...................... Statement of Financial Accounting Standards No.
143: Accounting for Asset Retirement
Obligations.
FERC......................... Federal Energy Regulatory Commission.
GAAP......................... Generally Accepted Accounting Principles.
Global Solar................. Global Solar Energy, Inc., a company that
develops and manufactures thin-film
photovoltaic cells. Millennium owns 87% of
Global Solar.
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.
IPS.......................... Infinite Power Solutions, Inc., a company that
develops thin-film batteries. Millennium owns
approximately 74% of IPS.
ITN.......................... ITN Energy Systems, Inc., was formed to provide
research, development, and other services.
Millennium currently owns 49% but has agreed to
reduce its ownership to 9%.
kWh.......................... Kilowatt-hour(s).
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 49% but
has agreed to reduce its ownership to 35%.
Millennium................... Millennium Energy Holdings, Inc., a wholly-
owned subsidiary of UniSource Energy.
MW........................... Megawatt(s).
MWh.......................... Megawatt-hour(s).
PG&E......................... Pacific Gas and Electric Company.
Revolving Credit Facility.... $60 million revolving credit facility entered
into under the Credit Agreement between a
syndicate of banks and TEP.
Rules........................ Retail Electric Competition Rules.
SCE.......................... Southern California Edison Company.
Settlement Agreement......... TEP's Settlement Agreement approved by the ACC
in November 1999 that provided for electric
retail competition and transition asset
recovery.
Springerville................ Springerville Generating Station.
Springerville Common
Facilities Leases.......... Leveraged lease arrangements relating to an
undivided one-half interest in certain
Springerville facilities used in common by
Springerville Unit 1 and Springerville Unit 2.
iv
DEFINITIONS
(concluded)
Springerville Unit 1......... Unit 1 of the Springerville Generating Station.
Springerville Unit 2......... Unit 2 of the Springerville Generating Station.
SRP.......................... Salt River Project Agricultural Improvement and
Power District.
TEP.......................... Tucson Electric Power Company, the principal
subsidiary of UniSource Energy.
Tri-State.................... Tri-State Generation and Transmission
Association.
TruePricing.................. TruePricing, Inc., a start-up company
established to market energy related products.
Millennium and TEP collectively own 51% of the
outstanding shares of TruePricing.
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.
UniSource Energy............. UniSource Energy Corporation.
v
Report of Independent Accountants
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 March 31, 2003 and
the related condensed consolidated statements of income (loss) and of cash
flows for each of the three-month periods ended March 31, 2003 and 2002 and
the condensed consolidated statement of changes in stockholders' equity for
the three-month period ended March 31, 2003. These financial statements are
the responsibility of the Company's and TEP's management.
We conducted our reviews in accordance with standards established by the
American Institute of Certified Public Accountants. A review of interim
financial information consists principally of applying analytical procedures
to financial data and making inquiries of persons responsible for financial
and accounting matters. It is substantially less in scope than an audit
conducted in accordance with generally accepted auditing standards, the
objective of which is the expression of an opinion regarding the financial
statements taken as a whole. Accordingly, we do not express such an opinion.
Based on our 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.
We previously audited in accordance with auditing standards generally
accepted in the United States of America, the consolidated balance sheet and
statement of capitalization of the Company and TEP as of December 31, 2002,
and the related consolidated statements 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 6, 2003 we expressed an
unqualified opinion on those consolidated financial statements. In our
opinion, the information set forth in the accompanying condensed consolidated
balance sheet information as of December 31, 2002 is fairly stated in all
material respects in relation to the consolidated balance sheets from which
it has been derived.
PricewaterhouseCoopers LLP
May 2, 2003
1
PART I - FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS
- -----------------------------------------------------------------------------
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME (LOSS)
Three Months Ended
March 31,
2003 2002
(Unaudited)
- -----------------------------------------------------------------------------
-Thousands of Dollars-
Operating Revenues
Electric Retail Sales $ 130,545 $ 131,832
Electric Wholesale Sales 40,170 35,546
Net Gain (Loss) on TEP Forward Contracts and
MEG Trading Activities (342) 1,021
Other Revenues 2,793 2,796
- -----------------------------------------------------------------------------
Total Operating Revenues 173,166 171,195
- -----------------------------------------------------------------------------
Operating Expenses
Fuel 46,502 48,319
Purchased Power 15,656 1,470
Other Operations and Maintenance 52,156 48,876
Depreciation and Amortization 30,520 33,450
Amortization of Transition Recovery Asset 3,608 2,882
Taxes Other Than Income Taxes 11,591 11,512
- -----------------------------------------------------------------------------
Total Operating Expenses 160,033 146,509
- -----------------------------------------------------------------------------
Operating Income 13,133 24,686
- -----------------------------------------------------------------------------
Other Income (Deductions)
Interest Income 5,234 4,756
Other Income 1,507 2,066
Other Expense (2,225) (1,871)
- -----------------------------------------------------------------------------
Total Other Income (Deductions) 4,516 4,951
- -----------------------------------------------------------------------------
Interest Expense
Long-Term Debt 19,272 15,972
Interest on Capital Leases 20,738 22,244
Other Interest Expense, Net of Amounts Capitalized (93) 231
- -----------------------------------------------------------------------------
Total Interest Expense 39,917 38,447
- -----------------------------------------------------------------------------
Loss Before Income Taxes and Cumulative Effect of
Accounting Change (22,268) (8,810)
Income Tax Benefit (8,067) (2,496)
- -----------------------------------------------------------------------------
Loss Before Cumulative Effect of Accounting Change (14,201) (6,314)
Cumulative Effect of Accounting Change - Net of Tax 67,471 -
- -----------------------------------------------------------------------------
Net Income (Loss) $ 53,270 $ (6,314)
=============================================================================
Average Shares of Common Stock Outstanding (000) 33,739 33,586
=============================================================================
Basic and Diluted Earnings per Share
Loss Before Cumulative Effect of Accounting Change $ (0.42) $ (0.19)
Cumulative Effect of Accounting Change - Net of Tax $ 2.00 -
Net Income (Loss) $ 1.58 $ (0.19)
=============================================================================
Dividends Paid per Share $ 0.15 $ 0.125
=============================================================================
See Notes to Condensed Consolidated Financial Statements.
2
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Three Months Ended
March 31,
2003 2002
(Unaudited)
- -------------------------------------------------------------------------------
-Thousands of Dollars-
Cash Flows from Operating Activities
Cash Receipts from Electric Retail Sales $ 153,697 $ 155,392
Cash Receipts from Electric Wholesale Sales 57,405 87,281
MEG Cash Receipts from Trading Activity 12,446 3,420
Interest Received 11,375 3,322
Fuel Costs Paid (49,760) (49,823)
Purchased Power Costs Paid (26,061) (56,299)
Wages Paid, Net of Amounts Capitalized (20,539) (21,696)
Payment of Other Operations and Maintenance Costs (27,341) (28,488)
MEG Cash Payments for Trading Activity (14,326) (4,799)
Capital Lease Interest Paid (41,967) (34,914)
Taxes Paid, Net of Amounts Capitalized (14,001) (14,408)
Debt Interest Paid, Net of Amounts Capitalized (25,362) (22,348)
Income Taxes Paid (4,367) (7,722)
Other (902) 254
- -------------------------------------------------------------------------------
Net Cash Flows - Operating Activities 10,297 9,172
- -------------------------------------------------------------------------------
Cash Flows from Investing Activities
Capital Expenditures (37,942) (27,060)
Investment in Springerville Lease Debt and Equity 8,778 (101,135)
Investment in and Loans to Equity Investees (4,606) (5,423)
Other (637) 5,425
- -------------------------------------------------------------------------------
Net Cash Flows - Investing Activities (34,407) (128,193)
- -------------------------------------------------------------------------------
Cash Flows from Financing Activities
Repayments of Long-Term Debt (1,261) (1,225)
Common Stock Dividends Paid (5,045) (4,198)
Payments on Capital Lease Obligations (37,374) (13,411)
Other 883 1,447
- -------------------------------------------------------------------------------
Net Cash Flows - Financing Activities (42,797) (17,387)
- -------------------------------------------------------------------------------
Net Decrease in Cash and Cash Equivalents (66,907) (136,408)
Cash and Cash Equivalents, Beginning of Year 90,928 228,154
- -----------------------------------------------------------------------------
Cash and Cash Equivalents, End of Period $ 24,021 $ 91,746
===============================================================================
SUPPLEMENTAL CONDENSED CONSOLIDATED CASH FLOW INFORMATION
- -------------------------------------------------------------------------------
Net Income (Loss) $ 53,270 $ (6,314)
Adjustments to Reconcile Net Income (Loss) to Net
Cash Flows
Cumulative Effect of Accounting Change - Net
of Tax (67,471) -
Depreciation and Amortization Expense 30,520 33,450
Depreciation Recorded to Fuel and Other
Other O&M Expense 1,448 1,417
Amortization of Transition Recovery Asset 3,608 2,882
Net Unrealized (Gain) Loss on Forward Electric
Sales and Purchases and MEG Trading Activities (1,783) (1,085)
Amortization of Deferred Debt-Related Costs
included in Interest Expense 732 484
Provision for Bad Debts 3,192 667
Deferred Income Taxes 19,192 (8,723)
Losses from Equity Method Entities 1,929 1,113
Other, Net 11,468 (5,366)
Changes in Current Assets and Liabilities which
Provided (Used) Cash Exclusive of Changes
Shown Separately:
Accounts Receivable 12,655 55,649
Materials and Fuel Inventory (4,405) (1,120)
Accounts Payable (5,269) (41,648)
Interest Accrued (28,580) (20,095)
Taxes Accrued (23,358) 7,963
Other Current Assets 934 (2,444)
Other Current Liabilities 2,215 (7,658)
- -------------------------------------------------------------------------------
Net Cash Flows - Operating Activities $ 10,297 $ 9,172
===============================================================================
See Notes to Condensed Consolidated Financial Statements.
3
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED BALANCE SHEETS
March 31, December 31,
2003 2002
(Unaudited)
- -------------------------------------------------------------------------------
-Thousands of Dollars-
ASSETS
Utility Plant
Plant in Service $ 2,609,615 $ 2,598,884
Utility Plant under Capital Leases 747,556 747,556
Construction Work in Progress 83,725 59,926
- -------------------------------------------------------------------------------
Total Utility Plant 3,440,896 3,406,366
Less Accumulated Depreciation and Amortization (1,254,988) (1,346,101)
Less Accumulated Depreciation of
Capital Lease Assets (399,218) (391,915)
- -------------------------------------------------------------------------------
Total Utility Plant - Net 1,786,690 1,668,350
- -------------------------------------------------------------------------------
Investments and Other Property
Investments in Lease Debt and Equity 182,867 191,867
Other 121,091 123,238
- -------------------------------------------------------------------------------
Total Investments and Other Property 303,958 315,105
- -------------------------------------------------------------------------------
Current Assets
Cash and Cash Equivalents 24,021 90,928
Trade Accounts Receivable 72,347 85,697
Allowance for Doubtful Accounts (11,559) (9,062)
Materials and Fuel Inventory 52,261 46,657
Trading Assets 22,808 15,150
Current Regulatory Assets 11,061 11,778
Deferred Income Taxes - Current 9,456 15,917
Interest Receivable - Current 6,337 12,178
Other 15,584 15,762
- -------------------------------------------------------------------------------
Total Current Assets 202,316 285,005
- -------------------------------------------------------------------------------
Regulatory and Other Assets
Transition Recovery Asset 303,512 307,120
Income Taxes Recoverable Through Future Revenues 55,245 57,044
Other Regulatory Assets 10,851 10,504
Other Assets 47,981 47,606
- -------------------------------------------------------------------------------
Total Regulatory and Other Assets 417,589 422,274
- -------------------------------------------------------------------------------
Total Assets $ 2,710,553 $ 2,690,734
===============================================================================
CAPITALIZATION AND OTHER LIABILITIES
Capitalization
Common Stock Equity $ 486,541 $ 438,229
Capital Lease Obligations 762,926 801,611
Long-Term Debt 1,127,829 1,128,963
- -------------------------------------------------------------------------------
Total Capitalization 2,377,296 2,368,803
- -------------------------------------------------------------------------------
Current Liabilities
Current Obligations under Capital Leases 48,900 42,960
Current Maturities of Long-Term Debt 1,832 1,840
Accounts Payable 43,202 48,934
Interest Accrued 26,953 60,238
Trading Liabilities 18,019 10,255
Taxes Accrued 10,492 33,850
Accrued Employee Expenses 12,097 13,644
Other 11,884 7,659
- -------------------------------------------------------------------------------
Total Current Liabilities 173,379 219,380
- -------------------------------------------------------------------------------
Deferred Credits and Other Liabilities
Deferred Income Taxes - Noncurrent 90,156 34,552
Other 69,722 67,999
- -------------------------------------------------------------------------------
Total Deferred Credits and Other Liabilities 159,878 102,551
- -------------------------------------------------------------------------------
Commitments and Contingencies (Note 9)
- -------------------------------------------------------------------------------
Total Capitalization and Other Liabilities $ 2,710,553 $ 2,690,734
===============================================================================
See Notes to Condensed Consolidated Financial Statements.
4
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, 2002 33,579 $661,185 $(218,932) $ (4,024) $438,229
- -------------------------------------------------------------------------------
Comprehensive Income:
2003 Year-to-Date
Net Income - - 53,270 - 53,270
-----------
Total Comprehensive
Income 53,270
-----------
Dividend Declared - - (5,045) - (5,045)
Shares Issued under
Stock Compensation
Plans 5 49 - - 49
Shares Distributed by
Deferred Compensation
Trust 1 9 - - 9
Shares Issued for
Stock Options 2 29 - - 29
- -------------------------------------------------------------------------------
Balances at
March 31, 2003 33,587 $661,272 $(170,707) $ (4,024) $486,541
===============================================================================
* UniSource Energy has 75 million authorized shares of common stock.
See Notes to Condensed Consolidated Financial Statements.
5
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME (LOSS)
Three Months Ended
March 31,
2003 2002
(Unaudited)
- -----------------------------------------------------------------------------
-Thousands of Dollars-
Operating Revenues
Electric Retail Sales $ 130,545 $ 131,832
Electric Wholesale Sales 40,170 35,546
Net Unrealized Gain on Forward Electric
Sales and Purchases 88 817
Other Revenues 1,744 1,382
- -----------------------------------------------------------------------------
Total Operating Revenues 172,547 169,577
- -----------------------------------------------------------------------------
Operating Expenses
Fuel 46,502 48,319
Purchased Power 15,656 1,470
Other Operations and Maintenance 45,301 44,268
Depreciation and Amortization 29,624 32,356
Amortization of Transition Recovery Asset 3,608 2,882
Taxes Other Than Income Taxes 11,150 11,112
- -----------------------------------------------------------------------------
Total Operating Expenses 151,841 140,407
- -----------------------------------------------------------------------------
Operating Income 20,706 29,170
- -----------------------------------------------------------------------------
Other Income (Deductions)
Interest Income 5,167 4,483
Interest Income - Note Receivable from
UniSource Energy 2,525 2,301
Other Income 975 1,176
Other Expense (265) (425)
- -----------------------------------------------------------------------------
Total Other Income (Deductions) 8,402 7,535
- -----------------------------------------------------------------------------
Interest Expense
Long-Term Debt 19,272 15,972
Interest on Capital Leases 20,734 22,230
Other Interest Expense, Net of Amounts Capitalized (247) 55
- -----------------------------------------------------------------------------
Total Interest Expense 39,759 38,257
- -----------------------------------------------------------------------------
Loss Before Income Taxes and
Cumulative Effect of Accounting Change (10,651) (1,552)
Income Tax Expense (Benefit) (3,475) 378
- -----------------------------------------------------------------------------
Loss Before Cumulative Effect of
Accounting Change (7,176) (1,930)
Cumulative Effect of Accounting Change - Net
of Tax 67,471 -
- -----------------------------------------------------------------------------
Net Income (Loss) $ 60,295 $ (1,930)
=============================================================================
See Notes to Condensed Consolidated Financial Statements.
6
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Three Months Ended
March 31,
2003 2002
(Unaudited)
- -----------------------------------------------------------------------------
-Thousands of Dollars-
Cash Flows from Operating Activities
Cash Receipts from Electric Retail Sales $ 153,697 $ 155,392
Cash Receipts from Electric Wholesale Sales 57,405 87,281
Interest Received 11,244 3,050
Fuel Costs Paid (49,760) (49,823)
Purchased Power Costs Paid (26,061) (56,299)
Wages Paid, Net of Amounts Capitalized (16,688) (18,011)
Payment of Other Operations and Maintenance Costs (24,570) (25,262)
Capital Lease Interest Paid (41,963) (34,893)
Taxes Paid, Net of Amounts Capitalized (12,965) (13,201)
Debt Interest Paid, Net of Amounts Capitalized (25,351) (22,342)
Income Taxes Paid (3,469) (7,667)
- -----------------------------------------------------------------------------
Net Cash Flows - Operating Activities 21,519 18,225
- -----------------------------------------------------------------------------
Cash Flows from Investing Activities
Capital Expenditures (37,095) (23,988)
Investment in Springerville Lease Debt and Equity 8,778 (101,135)
Other (952) 2,152
- -----------------------------------------------------------------------------
Net Cash Flows - Investing Activities (29,269) (122,971)
- -----------------------------------------------------------------------------
Cash Flows from Financing Activities
Repayments of Long-Term Debt (1,225) (1,225)
Payments on Capital Lease Obligations (37,347) (13,338)
Other 1,023 766
- -----------------------------------------------------------------------------
Net Cash Flows - Financing Activities (37,549) (13,797)
- -----------------------------------------------------------------------------
Net Decrease in Cash and Cash Equivalents (45,299) (118,543)
Cash and Cash Equivalents, Beginning of Year 55,778 159,680
- -----------------------------------------------------------------------------
Cash and Cash Equivalents, End of Period $ 10,479 $ 41,137
=============================================================================
SUPPLEMENTAL CONDENSED CONSOLIDATED CASH FLOW INFORMATION
- -----------------------------------------------------------------------------
Net Income (Loss) $ 60,295 $ (1,930)
Adjustments to Reconcile Net Income (Loss)
to Net Cash Flows
Cumulative Effect of Accounting Change
- Net of Tax (67,471) -
Depreciation and Amortization Expense 29,624 32,356
Depreciation Recorded to Fuel and Other
O&M Expense 1,448 1,417
Amortization of Transition Recovery Asset 3,608 2,882
Net Unrealized (Gain) Loss on Forward Electric
Sales and Purchases (88) (817)
Amortization of Deferred Debt-Related Costs
included in Interest Expense 732 484
Provision for Bad Debts 3,192 667
Deferred Income Taxes 15,432 (5,769)
Losses from Equity Method Entities (52) 91
Interest on Note Receivable from UniSource
Energy (2,525) (2,301)
Other, Net 1,747 2,448
Changes in Current Assets and Liabilities
which Provided (Used) Cash Exclusive of Changes
Shown Separately:
Accounts Receivable 22,989 52,334
Materials and Fuel Inventory (221) 63
Accounts Payable (5,339) (47,489)
Interest Accrued (28,580) (20,095)
Taxes Accrued (19,552) 7,852
Other Current Assets 7,024 (1,857)
Other Current Liabilities (744) (2,111)
- -----------------------------------------------------------------------------
Net Cash Flows - Operating Activities $ 21,519 $ 18,225
=============================================================================
See Notes to Condensed Consolidated Financial Statements.
7
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED BALANCE SHEETS
March 31, December 31,
2003 2002
(Unaudited)
- -----------------------------------------------------------------------------
-Thousands of Dollars-
ASSETS
Utility Plant
Plant in Service $ 2,609,615 $ 2,598,884
Utility Plant under Capital Leases 747,556 747,556
Construction Work in Progress 83,725 59,926
- -----------------------------------------------------------------------------
Total Utility Plant 3,440,896 3,406,366
Less Accumulated Depreciation and Amortization (1,254,988) (1,346,101)
Less Accumulated Depreciation of
Capital Lease Assets (399,218) (391,915)
- -----------------------------------------------------------------------------
Total Utility Plant - Net 1,786,690 1,668,350
- -----------------------------------------------------------------------------
Investments and Other Property
Investments in Lease Debt and Equity 182,867 191,867
Other 21,198 21,358
- -----------------------------------------------------------------------------
Total Investments and Other Property 204,065 213,225
- -----------------------------------------------------------------------------
Note Receivable from UniSource Energy 70,132 79,462
- -----------------------------------------------------------------------------
Current Assets
Cash and Cash Equivalents 10,479 55,778
Trade Accounts Receivable 58,097 76,736
Allowance for Doubtful Accounts (11,509) (9,012)
Intercompany Accounts Receivable 15,377 14,851
Materials and Fuel Inventory 45,921 44,500
Interest on Note Receivable from
UniSource Energy 11,855 -
Current Regulatory Assets 11,061 11,778
Deferred Income Taxes - Current 9,456 15,917
Interest Receivable - Current 6,337 12,178
Other 7,312 8,407
- -----------------------------------------------------------------------------
Total Current Assets 164,386 231,133
- -----------------------------------------------------------------------------
Regulatory and Other Assets
Transition Recovery Asset 303,512 307,120
Income Taxes Recoverable Through Future Revenues 55,245 57,044
Other Regulatory Assets 10,851 10,504
Other Assets 46,595 46,752
- -----------------------------------------------------------------------------
Total Regulatory and Other Assets 416,203 421,420
- -----------------------------------------------------------------------------
Total Assets $ 2,641,476 $ 2,613,590
=============================================================================
CAPITALIZATION AND OTHER LIABILITIES
Capitalization
Common Stock Equity $ 397,769 $ 337,463
Capital Lease Obligations 762,845 801,508
Long-Term Debt 1,127,185 1,128,410
- -----------------------------------------------------------------------------
Total Capitalization 2,287,799 2,267,381
- -----------------------------------------------------------------------------
Current Liabilities
Current Obligations under Capital Leases 48,813 42,872
Current Maturities of Long-Term Debt 1,725 1,725
Accounts Payable 35,918 41,704
Intercompany Accounts Payable 18,050 12,478
Interest Accrued 26,953 60,238
Taxes Accrued 16,220 35,772
Accrued Employee Expenses 11,762 13,370
Other 8,853 7,543
- -----------------------------------------------------------------------------
Total Current Liabilities 168,294 215,702
- -----------------------------------------------------------------------------
Deferred Credits and Other Liabilities
Deferred Income Taxes - Noncurrent 119,334 67,490
Other 66,049 63,017
- -----------------------------------------------------------------------------
Total Deferred Credits and Other Liabilities 185,383 130,507
- -----------------------------------------------------------------------------
Commitments and Contingencies (Note 9)
- -----------------------------------------------------------------------------
Total Capitalization and Other Liabilities $ 2,641,476 $ 2,613,590
=============================================================================
See Notes to Condensed Consolidated Financial Statements.
8
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, 2002 $ 653,529 $ (6,357) $(305,685) $ (4,024) $ 337,463
- -----------------------------------------------------------------------------
Comprehensive Income:
2003 Year-to-Date
Net Income - - 60,295 - 60,295
------------
Total Comprehensive
Income 60,295
------------
Other 11 - - - 11
- -----------------------------------------------------------------------------
Balances at
March 31, 2003 $ 653,540 $ (6,357) $(245,390) $ (4,024) $ 397,769
=============================================================================
See Notes to Condensed Consolidated Financial Statements.
9
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
- -----------------------------------------------------------------------------
NOTE 1. NATURE OF OPERATIONS AND BASIS OF ACCOUNTING PRESENTATION
- ------------------------------------------------------------------
UniSource Energy Corporation (UniSource Energy) is an exempt holding
company under the Public Utility Holding Company Act of 1935. UniSource Energy
has no significant operations of its own, but owns substantially all of the
common stock of Tucson Electric Power Company (TEP) and all of the common stock
of 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
represents substantially all of UniSource Energy's assets. TEP generates,
transmits and distributes electricity. TEP serves retail customers in a 1,155
square mile area in Southern Arizona. TEP also sells electricity to other
utilities and power marketing entities primarily located in the western U.S.
Millennium holds the unregulated businesses 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. References to the "utility business" are to TEP.
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 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 annual financial statements. This quarterly
report should be reviewed in conjunction with UniSource Energy and TEP's 2002
Annual Report on Form 10-K.
Weather causes seasonal fluctuations in TEP's sales; therefore, quarterly
results are not indicative of annual operating results. UniSource Energy and
TEP have made minor reclassifications to the prior year financial statements
for comparative purposes. These reclassifications had no effect on net income.
NOTE 2. REGULATORY ACCOUNTING
- ------------------------------
TEP generally uses 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 retail rates, the Arizona
Corporation Commission (ACC) may not allow TEP to currently charge its
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 defer these items and show them as regulatory assets on the balance sheet
until TEP is allowed to charge its customers. TEP then amortizes these items
as expense to the income statement as those 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:
- an independent regulator sets rates;
- the regulator sets the rates to recover specific costs of delivering
service; and
- the service territory lacks competitive pressures to reduce rates below
the rates set by the regulator.
In November 1999, upon approval by the ACC of a settlement agreement
(Settlement Agreement) relating to recovery of TEP's transition costs and
standard retail rates, TEP discontinued application of FAS 71 to its generation
operations.
TEP's regulatory assets total $381 million at March 31, 2003, $22 million
of which are not presently included in the rate base and consequently are not
earning a return on investment.
TEP continues to apply FAS 71 to the distribution and transmission
portions of its business, its regulated operations, and continues to assess
whether it can continue to apply FAS 71 to these operations. If TEP stopped
applying FAS 71 to its remaining regulated operations, it would write off the
related balances of its regulatory
10
assets as an expense on its income statement. Based on the balances of TEP's
regulatory assets at March 31, 2003, if TEP had stopped applying FAS 71 to its
remaining regulated operations, it would have recorded an extraordinary loss,
after-tax, of approximately $230 million. While regulatory orders and market
conditions may affect TEP's cash flows, its cash flows would not be affected if
it stopped applying FAS 71 unless a regulatory order limited its ability to
recover the cost of that regulatory asset.
RECENT DEVELOPMENTS IN THE ARIZONA REGULATORY ENVIRONMENT
In February 2003, the ACC issued an order that defines the process, for
the period 2003 through 2006, by which TEP will be required to obtain its
capacity and energy requirements beyond what is supplied by TEP's existing
resources, which represents approximately 0.5% of its retail load in the first
year and increases over the period. This order further requires TEP to bid out
short-term energy purchases that it estimates it will make in the 2003 to 2006
period; however, it does not require TEP to purchase any power that it deems to
be uneconomical, unreasonable or unreliable. TEP completed its review of the
proposals received and entered into the following two agreements to meet TEP's
2003 bid requirements under the Track B Order for the period 2003 through 2006:
(1) PPL EnergyPlus, LLC will supply 37 MW June 2003 through December 2003 and
75 MW January 2004 through December 2006 through a unit contingent contract;
and (2) Panda Gila River LP will supply 50 MW on-peak June through September of
2003 through 2005 through a unit contingent contract.
NOTE 3. ASSET PURCHASE AGREEMENTS
- ----------------------------------
On October 29, 2002, UniSource Energy entered into two Asset Purchase
Agreements with Citizens Communications Company (Citizens) for the purchase by
UniSource Energy of Citizens' Arizona electric utility and gas utility
businesses for a total of $230 million in cash. The purchase price of each
transaction is subject to adjustment based on the date the transaction closes
and, in each case, on the amount of certain assets and liabilities of the
purchased business at the time of closing. If the transaction closes before
July 28, 2003, the purchase price is reduced by $10 million. If the
transaction closes after October 29, 2003, the purchase price is increased by
$5 million. In addition, the purchase price in each transaction may also be
adjusted if there is a casualty loss, governmental taking, or discovery of
substantial additional environmental liabilities, in each case subject to
materiality thresholds, prior to the closing. UniSource Energy will assume
certain liabilities associated with the purchased assets, but will not assume
Citizens' obligations under the industrial development revenue bonds issued to
finance certain of the purchased assets for which Citizens will remain the
economic obligor. The asset purchases are expected to close in the second half
of 2003 after the conditions to the consummation of the transactions, including
federal and state regulatory approvals, are satisfied or waived.
The closing of the transactions is subject to approval by the ACC, the
Federal Energy Regulatory Commission (FERC) and the SEC under the Public
Utility Holding Company Act of 1935, as amended. As of March 31, 2003, all
required filings with the various governmental authorities have been made and
we are still waiting for approval from the ACC, the FERC and the SEC.
The Asset Purchase Agreements are subject to termination if the closing
has not occurred by January 29, 2004 (subject to extension in limited
circumstances), if a governmental authority seeks to prohibit the transactions,
if required regulatory approvals are not obtained with satisfactory terms and
conditions, or if either party is in material breach and such breach is not
cured. If one Asset Purchase Agreement is terminated, the other will also be
automatically terminated. If the Asset Purchase Agreements are terminated by
Citizens due to UniSource Energy's breach, UniSource Energy must pay to
Citizens a $25 million termination fee as liquidated damages. If the Asset
Purchase Agreements are terminated by UniSource Energy due to Citizens' breach,
Citizens must pay to UniSource Energy a $10 million termination fee as
liquidated damages. The termination fees are also payable in certain other
limited circumstances.
We expect that the purchase price will be financed by funds from UniSource
Energy and its affiliates and debt secured by the purchased assets. TEP is
limited by its credit agreement, however, as to the amount of affiliate
investments or loans it may make. TEP must also obtain ACC approval to make a
loan to an affiliate. Various financing alternatives are being discussed with
potential lenders and bridge financing arrangements are being evaluated.
UniSource Energy may also consider financing a portion of the purchase with new
equity, depending on market conditions and other considerations. If UniSource
Energy is unable to obtain financing and therefore fails to consummate the
purchase of these assets, this would constitute a breach under the contracts
and termination damages of $25 million would be payable.
11
PROPOSED SETTLEMENT AGREEMENT
Prior to entering into the Asset Purchase Agreements with UniSource
Energy, Citizens had two cases pending before the ACC requesting rate relief
for both the Arizona electric and Arizona gas assets. On April 1, 2003,
UniSource Energy and Citizens reached a proposed settlement agreement (Citizens
Settlement Agreement) with the ACC Staff addressing the rate case and financing
issues. If the ACC approves the Citizens Settlement Agreement, the changes in
rates and financing approvals will take effect once the acquisition is
completed, which is expected to occur by July 2003.
Under the terms of the Citizens Settlement Agreement, UniSource Energy
will form one or more wholly-owned subsidiaries to own and operate the acquired
assets (collectively, the New Companies) and it may also form an intermediate
holding company to finance and own the New Companies.
The Citizens Settlement Agreement includes the resolution of two pending
rate issues before the ACC: (1) a gas utility base rate case and (2) a review
of the electric utility purchase power and fuel adjustment clause. The
Citizens Settlement Agreement provides for a 20.9% increase in gas rates
compared with the 29% increase requested by Citizens. Because UniSource Energy
is acquiring the gas utility assets at a discounted purchase price, the amount
of rate recovery required is less than under the Citizens rate case. The gas
utility rate case also takes into account a $10 million permanent reduction to
the gas rate base due to a disallowance for certain capital expenditures for
gas infrastructure, thereby reducing the revenue level to be recovered from
ratepayers. In addition, the Citizens Settlement Agreement allows for a 22%
increase in electric utility rates, compared with the 45% requested by
Citizens. The allowed electric rate increase represents the full recovery in
rates of the costs of a long-term purchase power contract on a going forward
basis. At the same time, UniSource Energy agreed to forfeit the collection of
approximately $135 million in deferred purchased power costs under the same
contract that had been incurred by Citizens but had not been collected from
Citizens' customers. If the Citizens Settlement Agreement is approved, the
revised electric and gas tariffs would be effective upon the completion of the
acquisition. The Citizens Settlement Agreement also imposes a general rate
case moratorium for a period of three years from the date the ACC approves the
settlement order.
The financing provisions of the Citizens Settlement Agreement authorize
the New Companies to issue new debt and equity securities to fund the
acquisition of the Citizens gas and electric assets and to provide for initial
working capital requirements. The Citizens Settlement Agreement also
authorizes TEP to loan up to $50 million to UniSource Energy to fund the
purchase. In addition, the Citizens Settlement Agreement waives the existing
requirement that 30% of the proceeds of public stock issuance be invested in
TEP, so long as the purpose of the equity issuance is to help finance the
Citizens purchase.
The Citizens Settlement Agreement limits dividends from the New Companies
to 75% of earnings until the ratio of common equity to total capital return
reaches 40%. If approved, the Citizens Settlement Agreement would also modify
TEP's dividend limitation. Currently, TEP may not pay dividends in excess of
75% of its earnings until the ratio of common equity to total capital reaches
37.5%. Under the Citizens Settlement Agreement, the 75% earnings payout
limitation would remain in effect until TEP's ratio of common equity to total
capital reaches 40%.
The Citizens Settlement Agreement is subject to the review and approval of
the ACC and may be amended or supplemented prior to, or in conjunction with,
the approval. The ACC held hearings on the Citizens Settlement Agreement in
early May 2003. UniSource Energy expects that the ACC will act on the Citizens
Settlement Agreement by July 2003.
NOTE 4. ACCOUNTING CHANGE: ACCOUNTING FOR ASSET RETIREMENT OBLIGATIONS
- ------------------------------------------------------------------------
In June 2001, the Financial Accounting Standards Board (FASB) issued
Statement of Financial Accounting Standards No. 143, Accounting for Asset
Retirement Obligations (FAS 143). It requires entities to record the fair value
of a liability for a legal obligation to retire an asset in the period in which
the liability is incurred. A legal obligation is a liability that a party is
required to settle as a result of an existing or enacted law, statute,
ordinance or contract. When the liability is initially recorded, the entity
should capitalize a cost by increasing the carrying amount of the related long-
lived asset. Over time, the liability is adjusted to its present value by
recognizing accretion expense as an operating expense in the income statement
each period, and the capitalized cost is depreciated over the useful life of
the related asset. Upon settlement of the liability, an entity either settles
the obligation for its recorded amount or incurs a gain or loss if the actual
costs differ from the recorded amount.
12
Prior to adopting FAS 143, costs for final removal of all owned generation
facilities were accrued as an additional component of depreciation expense.
Under FAS 143, only the costs to remove an asset with legally binding
retirement obligations will be accrued over time through accretion of the asset
retirement obligation and depreciation of the capitalized asset retirement
cost.
TEP has identified legal obligations to retire generation plant assets
specified in land leases for its jointly-owned Navajo and Four Corners
Generating Stations. The land on which the Navajo and Four Corners Generating
Stations reside is leased from the Navajo Nation. The provisions of the leases
require the lessees to remove the facilities upon request of the Navajo Nation
at the expiration of the leases. TEP also has certain environmental
obligations at the San Juan Generating Station (San Juan). TEP has estimated
that its share of the cost to remove the Navajo and Four Corners facilities and
to settle the San Juan environmental obligations is approximately $38 million
at the date of retirement. No other legal obligations to retire generation
plant assets were identified. Millennium and UED have no asset retirement
obligations.
TEP has various transmission and distribution lines that operate under
land leases and rights of way that contain end dates and restorative clauses.
TEP operates its transmission and distribution lines as if they will be
operated in perpetuity and would continue to be used or sold without land
remediation. As a result, TEP will not recognize the costs of final removal of
the transmission and distribution lines in the financial statements.
Upon adoption of FAS 143 on January 1, 2003, TEP recorded an asset
retirement obligation of $38 million at its net present value of $1.1 million,
increased depreciable assets by $0.1 million for asset retirement costs,
reversed $112.8 million of costs previously accrued for final removal from
accumulated depreciation, reversed previously recorded deferred tax assets of
$44.2 million and recognized the cumulative effect of accounting change as a
gain of $111.7 million ($67.5 million net of tax). TEP expects that adopting
FAS 143 will result in a reduction to current depreciation expense charged
throughout the year as well because asset retirement costs are no longer
recorded as a component of depreciation expense. For the year 2003, this
amount is approximately $6 million.
The following table illustrates on a pro forma basis the amount of the
asset retirement obligation as if FAS 143 had been applied during all periods
presented:
Three Months Ended
March 31,
2003 2002
Actual Pro Forma
----------------------------------------------------------------
-Thousands of Dollars-
Asset Retirement Obligation -
beginning of period $ 1,119 $ 1,017
Accretion Expense 27 25
----------------------------------------------------------------
Asset Retirement Obligation -
end of period $ 1,146 $ 1,042
================================================================
The following table illustrates on a pro forma basis the effect on
UniSource Energy's net income and earnings per share and TEP's net income as if
FAS 143 had been in effect for all income statement periods presented:
UniSource Energy:
- ----------------
Three Months Ended
March 31, 2002
----------------------------------------------------------------
-Thousands of Dollars-
(except per share data)
Net Loss - As Reported $ (6,314)
Adjustment to accrued expense (net
of tax) as if FAS 143 had been applied
effective January 1, 2002 912
----------------------------------------------------------------
Pro Forma Net Loss $ (5,402)
================================================================
Basic and Diluted Earnings per Share:
As Reported $ (0.19)
Adjustment to accrued expense (net
of tax) as if FAS 143 had been applied
effective January 1, 2002 .03
----------------------------------------------------------------
Pro Forma $ (0.16)
================================================================
13
TEP:
- ---
Three Months Ended
March 31, 2002
----------------------------------------------------------------
-Thousands of Dollars-
(except per share data)
Net Loss - As Reported $ (1,930)
Adjustment to accrued expense (net
of tax) as if FAS 143 had been applied
effective January 1, 2002 912
----------------------------------------------------------------
Pro Forma Net Loss $ (1,018)
================================================================
Amounts recorded under FAS 143 are subject to various assumptions and
determinations, such as determining whether a legal obligation exists to remove
assets, estimating the fair value of the costs of removal, estimating when
final removal will occur, and the credit-adjusted risk-free interest rates to
be used to discount future liabilities. Changes that may arise over time with
regard to these assumptions and determinations will change amounts recorded in
the future as expense for asset retirement obligations.
If TEP retires any asset at the end of its useful life, without a legal
obligation to do so, it will record retirement costs at that time as incurred
or accrued. TEP does not believe that the adoption of FAS 143 will result in
any change in retail rates since all matters relating to the rate-making
treatment of TEP's generating assets were determined pursuant to the Settlement
Agreement.
NOTE 5. STOCK-BASED COMPENSATION
- ---------------------------------
At March 31, 2003, UniSource Energy has two stock-based compensation
plans, the 1994 Outside Director Stock Option Plan (Directors' Plan) and the
1994 Omnibus Stock and incentive Plan (Omnibus Plan). We account for those
plans under the recognition and measurement principles of APB Opinion No. 25,
Accounting for Stock Issued to Employees, and related interpretations.
STOCK OPTIONS
No compensation cost is reflected in net income for stock options, as all
options granted had an exercise price equal to the market value of the
underlying common stock on the date of grant.
The Directors' Plan granted 21,222 stock options in the first quarter of
2003 and 22,000 options in the first quarter of 2002. Additionally, the
Compensation Committee of the UniSource Energy Board of Directors granted
568,000 stock options to key employees under the Omnibus Plan in the first
quarter of 2002. These options vest over three years, become exercisable in one-
third increments on each anniversary date of the grant and expire on the tenth
anniversary of the grant.
A summary of the stock option activity of the Directors' Plan and Omnibus
Plan is as follows:
Three Months Ended March 31,
2003 2002
------------------------------------------------------------------
Weighted Weighted
Average Average
Exercise Exercise
Shares Price Shares Price
------------------------------------------------------------------
Options Outstanding,
Beginning of Period 2,576,819 $15.77 2,075,234 $15.05
Granted 21,222 $17.44 590,000 $18.14
Exercised (2,257) $12.61 (48,104) $14.65
Forfeited (2,866) $13.76 (6,953) $14.67
---------- ----------
Options Outstanding,
End of Period 2,592,918 $15.79 2,610,177 $15.76
========== =========
Options Exercisable,
End of Period 1,644,400 $14.91 1,049,188 $14.37
========== =========
Weighted Average Remaining
Contractual Life at March 31, 2003: 6.72
------------------------------------------------------------------
14
The following table illustrates the effect on UniSource Energy's net
income and earnings per share and TEP's net income if we had applied the fair
value recognition provisions of Statement of Financial Accounting Standards No.
123, Accounting for Stock-Based Compensation, to stock-based employee
compensation:
UniSource Energy:
- ----------------
Three Months Ended March 31,
2003 2002
----------------------------------------------------------------
-Thousands of Dollars-
(except per share data)
Net Income (Loss) - As Reported $ 53,270 $ (6,314)
Deduct: Total stock-based employee
compensation expense determined under
fair value based method, net of
related tax effects (238) (318)
----------------------------------------------------------------
Pro Forma Net Income (Loss) $ 53,032 $ (6,632)
================================================================
Basic and Diluted Earnings per Share:
As Reported $1.58 $(0.19)
Pro Forma $1.57 $(0.20)
================================================================
TEP:
- ---
Three Months Ended March 31,
2003 2002
----------------------------------------------------------------
-Thousands of Dollars-
(except per share data)
Net Income (Loss) - As Reported $ 60,295 $ (1,930)
Deduct: Total stock-based employee
compensation expense determined under
fair value based method, net of
related tax effects (235) (314)
----------------------------------------------------------------
Pro Forma Net Income (Loss) $ 60,060 $ (2,244)
================================================================
The fair value of each stock option grant is estimated on the date of
grant using the Black-Scholes option-pricing model with the following weighted
average assumptions:
2003 2002
----------------------------------------------------------------
Expected life (years) 6 5
Interest rate 3.34% 1.45%
Volatility 23.74% 23.74%
Dividend yield 3.55% 2.83%
Weighted-average grant-date fair value
of options granted during the period $3.16 $2.90
----------------------------------------------------------------
RESTRICTED STOCK UNITS
During the quarter ended March 31, 2003, 573 restricted shares or stock
units were awarded under the Directors' Plan to each of nine directors, for a
total of 5,157 shares or units. The restricted shares or stock units become
100% vested on the third anniversary of the grant date. Compensation expense
equal to the fair market value on the date of award is recognized over the
vesting period. These equity instruments were issued at a fair market value of
$17.44.
NOTE 6. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND TRADING ACTIVITIES
- ---------------------------------------------------------------------
TEP enters into forward contracts to purchase or sell a specified amount
of capacity or energy at a specified price over a given period of time,
typically for one month, three months, or one year, within established limits
to take advantage of favorable market opportunities. In general, TEP enters
into forward purchase contracts when market conditions provide the opportunity
to purchase for its load at prices that are below the marginal cost of its
supply resources or when additional supply is needed in addition to TEP's own
resources (i.e., during plant outages and summer peaking periods). TEP enters
into forward sales contracts when TEP forecasts that it has
15
excess supply and the market price of energy exceeds its marginal cost. The
majority of TEP's forward contracts are considered normal purchases and sales
under Statement of Financial Accounting Standards No. 133, Accounting for
Derivative Instruments and Hedging Activities (FAS 133) and, therefore, are not
required to be marked to market. However, some of these forward contracts are
considered to be derivatives, which TEP marks to market under FAS 133 by
recording unrealized gains and losses and adjusting the related assets and
liabilities on a monthly basis to reflect the market prices at the end of the
month.
TEP 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.
Millennium Environmental Group, Inc. (MEG), a wholly-owned subsidiary of
Millennium, enters into swap agreements, options and forward contracts relating
to emission allowances and coal. MEG also marks its trading contracts to
market under FAS 133 by recording unrealized gains and losses and adjusting the
related assets and liabilities on a monthly basis to reflect the market prices
at the end of the month.
The market prices used to determine fair value for TEP and MEG's
derivative instruments are estimated based on various factors including broker
quotes, exchange prices, over the counter prices and time value.
TEP and MEG's derivative activities are reported as follows:
- TEP's unrealized gain/loss on forward sales and purchase contracts is a
component of Operating Revenues;
- TEP's realized gain/loss on forward sales contracts is a component of
Electric Wholesale Revenues;
- TEP's realized gain/loss on forward purchase contracts is a component of
Purchased Power; and
- MEG's unrealized and realized gain/loss on trading activities are
components of Operating Revenues.
During the three months ended March 31, 2003, MEG physically settled the
purchase of 143,000 emission allowances and the sale of 121,000 emission
allowances under its trading contracts.
The net pre-tax gains (losses) were as follows:
Three Months Ended
March 31,
2003 2002
---------------------------------------------------------------
-Millions of Dollars-
TEP's Unrealized Gain on Derivative
Forward Contracts $ 0.1 $ 0.8
MEG's Unrealized and Realized Gain
(Loss) on Trading Activities (0.4) 0.2
---------------------------------------------------------------
UniSource Energy Net Gain (Loss) on
TEP's Forward Contracts and MEG's
Trading Activities $(0.3) $ 1.0
===============================================================
At March 31, 2003, the fair value of TEP's derivative assets was $0.1
million and is reported in Other Current Assets. At December 31, 2002, TEP had
no open forward contracts that were considered derivatives. MEG's trading
assets are reported in Current Assets and MEG's trading liabilities are
reported in Current Liabilities. At March 31, 2003 and December 31, 2002, the
fair value of MEG's trading assets was $22.8 million and $15.1 million,
respectively, including MEG's emission allowance inventory. At March 31, 2003
and December 31, 2002, the fair value of MEG's trading liabilities was $18.0
million and $10.3 million, respectively.
NOTE 7. BUSINESS SEGMENTS
- --------------------------
Based on the way we organize our operations and evaluate performance, we
have three reportable business segments:
(1) TEP, an electric utility business, is UniSource Energy's largest
subsidiary.
(2) Millennium holds interests in unregulated businesses (see Note 8).
(3) UED, established in 2001, is responsible for developing the expansion
project at the Springerville Generating Station. Prior to September 2002, UED
owned a 20 MW gas turbine, which it leased to TEP. In September 2002, UED sold
the turbine to TEP for its net book value of $15 million.
16
UniSource Energy's significant reconciling adjustments consist of the
elimination of intercompany activity and balances. Millennium recorded revenue
from transactions with TEP of $2 million and $2.5 million in the three months
ended March 31, 2003 and March 31, 2002, respectively. 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; and the elimination of
UED's rental income and TEP's rental expense from UED's turbine lease to TEP
prior to UED's sale of the turbine to TEP in September 2002.
We record our percentage share of the earnings of affiliated companies
when we hold a 20% to 50% voting interest, except for investments where we
provide all of the financing, in which case we recognize 100% of the losses.
See Note 8.
We disclose selected financial data for our business segments in the
following tables:
Segments UniSource
------------------------ Reconciling Energy
TEP Millennium UED Adjustments Consolidated
- ------------------------------------------------------------------------------
-Thousands of Dollars-
Income Statement
- ----------------
Three months ended
March 31, 2003:
- ------------------------------------------------------------------------------
Operating Revenues -
External $ 172,485 $ 681 $ - $ - $ 173,166
- ------------------------------------------------------------------------------
Operating Revenues -
Intersegment 62 2,036 - (2,098) -
- ------------------------------------------------------------------------------
Loss Before Income
Taxes and Cumulative
Effect of Accounting
Change (10,651) (8,275) (199) (3,143) (22,268)
- ------------------------------------------------------------------------------
Net Income (Loss) 60,295 (5,005) (120) (1,900) 53,270
- ------------------------------------------------------------------------------
Three months ended
March 31, 2002:
- ------------------------------------------------------------------------------
Operating Revenues -
External $ 169,392 $ 1,803 $ - $ - $ 171,195
- ------------------------------------------------------------------------------
Operating Revenues -
Intersegment 185 2,539 840 (3,564) -
- ------------------------------------------------------------------------------
Income (Loss) Before
Income Taxes (1,552) (5,462) 505 (2,301) (8,810)
- ------------------------------------------------------------------------------
Net Income (Loss) (1,930) (3,300) 305 (1,389) (6,314)
- ------------------------------------------------------------------------------
Balance Sheet
- -------------
Total Assets,
March 31, 2003 $2,641,476 $146,788 $ 38,919 $(116,630) $2,710,553
Total Assets,
December 31, 2002 2,613,590 151,468 37,839 (112,163) 2,690,734
- ------------------------------------------------------------------------------
NOTE 8. MILLENNIUM
- -------------------
ENERGY AND TECHNOLOGY INVESTMENTS
We refer to Global Solar Energy, Inc. (Global Solar), Infinite Power
Solutions, Inc. (IPS), MicroSat Systems, Inc. (MicroSat) and ITN Energy
Systems, Inc. (ITN) as our Energy and Technology Investments.
- Global Solar - Millennium funded $4 million to Global Solar in the first
quarter of 2003, and $0.8 million in April 2003. Millennium's unfunded
commitment to Global Solar is currently a $5 million line of credit committed
in May 2003. On February 21, 2003, Global Solar signed a license agreement
with ICP Global Technologies, a privately held Canadian solar product firm.
Millennium owns 87% of Global Solar, but as sole funder recognizes 100% of
their losses. Global Solar has an annual $0.5 million research and development
funding commitment to ITN through 2004.
- IPS - Millennium funded $1 million to IPS in the first quarter of 2003.
Dow Corning Enterprises, Inc. (Dow Corning) funded a corresponding $1 million.
In May 2003, Millennium and Dow Corning each funded an additional $0.5 million.
The investments were in exchange for preferred shares of IPS. Millennium
expects to commit an additional $1.5 million to IPS in the second quarter of
2003. As of March 31, 2003, Millennium owns approximately 74% of IPS and for
the first quarter of 2003 Millennium has recorded its ratable share of IPS's
losses. Millennium anticipates it will ultimately own between 59% and 72% of
IPS. IPS has a $0.5 million annual research and development funding commitment
to ITN though 2004.
17
- MicroSat - Millennium owns 49% of MicroSat, but as sole funder
recognizes 100% of their losses. Millennium anticipates its ownership of
MicroSat will be reduced to 35% in 2003, based on a 2002 Restructure Agreement.
- ITN - Millennium owns 49% of ITN, but anticipates its ownership will be
reduced to 9% in 2003, based on a 2002 Restructure Agreement. Millennium, as
sole funder, continues to recognize 100% of ITN's losses.
Millennium expects to fund an additional $7 million to $10 million to
these entities during the remainder of 2003. A significant portion of this
funding will be used for research, development and administrative costs and
will be recognized as expense.
OTHER MILLENNIUM INVESTMENTS AND COMMITMENTS
Millennium has a $15 million capital commitment to Haddington Energy
Partners II LP (Haddington), a limited partnership which funds energy-related
investments. During the first quarter of 2003, Millennium invested
approximately $2 million in Haddington. Millennium has satisfied $8.1 million
of the $15 million commitment to date. The remaining $6.9 million is expected
to be funded within the next three years. A member of the UniSource Energy
Board of Directors has an investment in the limited partnership and is also a
managing director of the general partner of the limited partnership.
Millennium has a $6 million capital commitment to a venture capital fund
that will focus on information technology, microelectronics and biotechnology,
primarily within the southwestern U.S. A member of the UniSource Energy Board
of Directors is a general partner of the company that manages the fund. At
March 31, 2003, Millennium had funded approximately $1 million of this
commitment. Millennium does not expect to provide any additional funds to this
investment in 2003.
During the first quarter of 2003, Millennium contributed $0.4 million to
TruePricing, Inc. (TruePricing) and agreed to provide up to an additional $0.8
million in future funding. Following this investment Millennium began
accounting for TruePricing under the consolidation method. Millennium and TEP
collectively now own 51% of the outstanding shares of TruePricing. Previously,
Millennium accounted for TruePricing under the equity method. Millennium, as
sole funder, recognizes 100% of TruePricing's losses.
NATIONS ENERGY CONTINGENCY
In September 2001, Nations Energy Corporation (Nations Energy) sold its
26% equity interest in a power project located in Curacao, Netherland Antilles
to a subsidiary of Mirant Corporation (Mirant). Nations Energy received $5
million in cash and an $11 million note receivable from the sale. The note was
recorded at its net present value of $8 million using an 8% discount rate, the
discount being amortized to interest income over the five-year life of the
note. The note is included in Investments and Other Property - Other on
UniSource Energy's balance sheets. The note is guaranteed by Mirant Americas,
Inc., a subsidiary of Mirant. Payments on the note receivable are expected as
follows: $2 million in July 2004, $4 million in July 2005, and $5 million in
July 2006.
In late 2002 and continuing in 2003, the major rating agencies downgraded
the ratings of Mirant and certain of its subsidiaries citing Mirant's
significantly lower operating cash flow relative to its debt burden coupled
with the likelihood that future operating cash flow levels may weaken further.
Mirant's ratings are now below investment grade. As of March 31, 2003, Nations
Energy's receivable from Mirant is approximately $9.4 million. We cannot
predict what effect the downgrades of Mirant's ratings will have on its ability
to make its required payments to Nations Energy when due, beginning in July
2004. Although Nations Energy has not recorded an allowance for doubtful
accounts, we will continue to evaluate the collectibility of the receivable.
NOTE 9. COMMITMENTS AND CONTINGENCIES
- --------------------------------------
TEP CONTINGENCIES
Springerville Generating Station Complaint
Environmental activist groups have expressed concerns regarding the
construction of any new units at the Springerville Generating Station. In
January 2003, environmental activist groups appealed an ACC Order affirming
18
the ACC's approval of the expansion at Springerville Generating Station to the
Superior Court of the State of Arizona.
Additionally, 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 and that new permits and the installation of additional
facilities meeting Best Available Control Technology standards are required for
the continued operation of Units 1 and 2 in accordance with applicable law. 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. TEP believes these claims are without merit and will vigorously
contest them.
Litigation Related to San Juan Coal Company
On July 30, 2002, Dugan Production Corp. (Dugan) filed a lawsuit against
the San Juan Coal Company, the coal supplier to San Juan. TEP owns 50% of San
Juan Units 1 and 2, which equates to 19.8% of San Juan in total. The San Juan
Coal Company, through leases with the federal government and the State of New
Mexico, owns coal interests with respect to an underground mine. Dugan,
through leases with the federal government, the State of New Mexico and certain
private parties, claims to own certain oil and gas interests in portions of the
land used for the underground mine. Dugan alleges that San Juan Coal Company's
underground coal mining operations have or will interfere with Dugan's gas
production and will reduce the amount of natural gas that Dugan would otherwise
be entitled to recover. Dugan seeks a declaration by the court that the rights
under its leases are senior and superior to the rights of the San Juan Coal
Company and seeks to prohibit the underground mining of coal from a portion of
the land used for the underground mine as described above. Dugan also seeks
monetary damages.
The San Juan Coal Company has informed Public Service Company of New
Mexico (PNM) that it intends to strongly dispute the litigation. TEP cannot
predict the ultimate outcome of this litigation, or whether it will adversely
affect the amount of coal available or cost of coal to San Juan. TEP does not
expect resolution of this litigation to be material to TEP as a 19.8% owner of
San Juan.
Litigation 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 PNM as
operator of San Juan. The lawsuit, which alleges two violations of the Clean
Air Act and related regulations and permits, seeks penalties as well as
injunctive and declaratory relief and is presently scheduled for trial in the
third quarter of 2003. Based on its investigation to date, PNM has stated that
it firmly believes that the allegations are without merit, and vigorously
disputes the allegations. Only one of those allegations relates to a unit in
which TEP owns an interest. While TEP is unable to predict the ultimate
outcome of the lawsuit, TEP does not believe the outcome will be material to
TEP.
Postretirement and Pension Benefit Costs at Various Generating Stations
Certain coal suppliers have submitted demands for payment by TEP of
postretirement and pension benefit costs for these coal suppliers' employees
under the coal suppliers' agreements with various TEP generating stations. As
amounts become known and payment probable, TEP will record a liability for
additional postretirement and pension benefit costs at these generating
stations.
Environmental Reclamation at Remote Generating Stations
TEP pays on-going reclamation costs at each of its remote generating
stations, and it is reasonably possible that TEP may have to pay a portion of
final reclamation costs at the mines which supply the remote generating
stations. As amounts become known and probable, TEP will record a liability
for final reclamation.
19
TEP COMMITMENTS
See Note 2 for a description of TEP's power purchase agreements.
MILLENNIUM COMMITMENTS
See Note 8 for a description of Millennium's commitments.
UED COMMITMENTS
UED and Salt River Project Agricultural Improvement and Power District
(SRP) entered into a Joint Development Agreement in October 2001 to develop two
400 MW coal-fired units at TEP's existing Springerville Generating Station. As
a result of recent developments, UED and SRP are modifying the Joint
Development Agreement to provide for SRP's purchase of a specified amount of
power from Unit 3 and SRP's right to construct and own Unit 4 at a later date.
UED and SRP each committed project development funding for professional
services and other third party costs. As of December 31, 2002, SRP met its
funding commitment for the project. Tri-State Generation and Transmission
Association, Inc. (Tri-State) has agreed to purchase the remaining power from
Unit 3 and will be the owner of the facility. Tri-State and UED signed a
Development Cost Agreement in January 2003 to each share 50% of the remaining
development costs of Unit 3 effective from November 6, 2002 until financial
closing. At March 31, 2003, capitalized project development costs on UniSource
Energy's balance sheet were approximately $23 million. Management believes it
is probable that UED will proceed with this project. If the project does not
proceed, the capitalized project development costs will be immediately
expensed.
GUARANTEES AND INDEMNITIES
In the normal course of business, UniSource Energy and certain
subsidiaries, including TEP, enter into various agreements providing financial
or performance assurance to third parties on behalf of certain subsidiaries.
These agreements are entered into primarily to support or enhance the
creditworthiness otherwise attributed to a subsidiary on a stand-alone basis,
thereby facilitating the extension of sufficient credit to accomplish the
subsidiaries' intended commercial purposes. The most significant of these
guarantees is Millennium's guarantee of approximately $3.5 million in commodity-
related payments for MEG at March 31, 2003. 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 UniSource Energy or TEP would be required
to perform or otherwise incur any significant losses associated with any of
these guarantees is remote.
NOTE 10. WHOLESALE ACCOUNTS RECEIVABLE AND ALLOWANCES
- ------------------------------------------------------
At March 31, 2003, TEP's Allowance for Doubtful Accounts on the balance
sheet includes $11 million for uncollectible receivables related to 2000 and
2001 sales to the California Power Exchange (CPX), the California Independent
System Operator (CISO) and Enron Corp. and certain of its affiliates (Enron).
At December 31, 2002, the allowance for these receivables was $8 million.
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 has held hearings and 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. As of December 31, 2002, TEP had reserved $8 million, or 50%, of its
outstanding receivable based on the amount TEP believed would be collected.
Based upon the most recent FERC order in March 2003, TEP estimates that it may
receive approximately $6 million of its $16 million receivable. This
represents amounts owed to TEP net of TEP's estimated refund liability.
Therefore, in the first quarter of 2003, TEP increased its reserve for sales to
the CPX and the CISO by $2.2 million by recording a reduction of wholesale
revenues.
20
Additionally, a recent FERC order recommended that Enron no longer be
allowed to trade and within a few days thereafter, Enron was delisted from its
stock exchange. As a result, in the first quarter of 2003, TEP increased its
reserve for sales to Enron by $0.4 million, to 100% of its $0.8 million
recorded receivable from Enron.
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, and concerning Enron. We cannot predict the
outcome of these issues or lawsuits. We believe, however, that TEP is
adequately reserved for its transactions with the CPX, the CISO and Enron.
TEP's Accounts Receivable from Electric Wholesale Sales are included in
Trade Accounts Receivable on the balance sheet. TEP's wholesale receivables,
net of allowances, totaled $22 million at March 31, 2003 and $31 million at
December 31, 2002. Excluding the receivables from the CPX, the CISO and Enron,
as described above, substantially all of the March 31, 2003 wholesale
receivable balance has been collected as of the date of this filing.
NOTE 11. UNISOURCE ENERGY EARNINGS PER SHARE (EPS)
- ---------------------------------------------------
Basic EPS is computed by dividing net income (loss) by the weighted
average number of common shares outstanding during the period. Diluted EPS
assumes that proceeds from the hypothetical exercise of stock options and other
stock-based awards are used to repurchase outstanding shares of stock at the
average fair market price during the reporting period. There are no reconciling
items in calculating the numerator and denominator for basic and diluted net
income (loss) per share for any periods presented.
The dilutive share bases for the quarters ended March 31, 2003 and March
31, 2002 exclude incremental common shares related to options, warrants and
contingently issuable shares of 1,406,000 and 715,000, respectively. These
shares are excluded due to their antidilutive effect as a result of UniSource
Energy's loss before cumulative effect of accounting change for the quarter
ended March 31, 2003 and UniSource Energy's net loss for the quarter ended
March 31, 2002.
At March 31, 2003, UniSource Energy and TEP had no outstanding warrants.
At March 31, 2002, there were 4.6 million warrants outstanding that were
exercisable into TEP common stock at a ratio of five warrants to one common
share. These warrants expired unexercised on December 15, 2002. The dilutive
effect of these warrants was the same as it would have been if the warrants
were exercisable into UniSource Energy Common Stock.
NOTE 12. 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:
UniSource Energy TEP
------------------ ------------------
Three Months Ended Three Months Ended
March 31, March 31,
2003 2002 2003 2002
- ------------------------------------------------------------------------------
-Thousands of Dollars-
Federal Income Tax (Benefit) at
Statutory Rate $(7,794) $(3,084) $(3,728) $ (543)
State Income Tax (Benefit), Net
of Federal Deduction (1,024) (406) (490) (71)
Depreciation Differences (Flow
Through Basis) 1,086 1,154 1,086 1,154
Tax Credits (380) (206) (380) (206)
Other 45 46 37 44
Tax on Cumulative Effect of
Accounting Change (see Note 4) 44,236 - 44,236 -
- ------------------------------------------------------------------------------
Total Expense (Benefit) for Federal
and State Income Taxes $36,169 $(2,496) $40,761 $ 378
==============================================================================
21
OTHER TAXES
TEP acts as a conduit or collection agent for excise tax (sales tax) as
well as franchise fees and regulatory assessments. TEP records liabilities
payable to governmental agencies when TEP bills its customers for these
amounts. Neither the amounts billed nor payable are reflected in the income
statement.
NOTE 13. NEW ACCOUNTING PRONOUNCEMENTS
- ---------------------------------------
The FASB recently issued the following Statement of Financial Accounting
Standards (FAS) and FASB Interpretations (FIN):
- FIN 45, Guarantor's Accounting and Disclosure Requirements for
Guarantees, Including Indirect Guarantees of Indebtedness of Others, issued
November 2002, requires disclosures to be made by a guarantor in its interim
and annual financial statements about its obligations under certain guarantees
that it has issued. FIN 45 also clarifies that a guarantor is required to
recognize, at the inception of a guarantee, a liability for the fair value of
the obligation undertaken in issuing the guarantee. The initial recognition
and initial measurement provisions of FIN 45 are applicable on a prospective
basis to guarantees issued or modified beginning January 1, 2003. The
disclosure requirements of FIN 45 are immediately effective. See Guarantees
and Indemnities in Note 9, above.
- FIN 46, Consolidation of Variable Interest Entities, issued January
2003, expands upon existing guidance that addresses when a company should
include in its financial statements the assets and liabilities of another
entity. The primary objectives of FIN 46 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 enterprise should consolidate the variable interest entity
(primary beneficiary). FIN 46 requires that both the primary beneficiary and
all other enterprises with a significant variable interest make additional
disclosures. The transitional disclosure requirements of FIN 46 are effective
immediately. The effective date of the consolidation requirements of FIN 46
depends on the date the variable interest entity was created. FIN 46 is
effective for all variable interest entities created after January 31, 2003.
For variable interest entities created before February 1, 2003, the provisions
of FIN 46 are to be applied to a variable interest entity for interim reporting
periods beginning after June 30, 2003. UniSource Energy's investments in
MicroSat and ITN are accounted for under the equity method (see Note 8, above).
UniSource Energy is the primary funding source for these investments and
recognizes all of the losses. UniSource Energy may be required to consolidate
MicroSat and ITN beginning July 1, 2003. The consolidation of MicroSat and ITN
would not have a material impact on UniSource Energy's financial statements, as
these entities do not presently have significant assets or debt from outside
third parties.
- FAS 149, Amendment of Statement 133 on Derivative Instruments and
Hedging Activities, was issued by the FASB in April 2003. FAS 149 amends and
clarifies accounting for derivative instruments, including certain derivative
instruments embedded in other contracts, and for hedging activities under FAS
133. FAS 149 is effective for contracts entered into or modified after June
30, 2003, except as stated below, and for hedging relationships designated
after June 30, 2003. The guidance should be applied prospectively. The
provisions of FAS 149 that relate to FAS 133 Implementation Issues that have
been effective for fiscal quarters that began prior to June 15, 2003, should
continue to be applied in accordance with their respective effective dates.
Due to TEP and MEG's limited amount of derivative activity, we do not expect
the adoption of FAS 149 to have a significant effect on UniSource Energy or
TEP's financial statements.
NOTE 14. REVIEW BY INDEPENDENT ACCOUNTANTS
- -------------------------------------------
With respect to the unaudited condensed consolidated financial information
of UniSource Energy and TEP for the three-month periods ended March 31, 2003
and 2002, PricewaterhouseCoopers LLP reported that they have applied limited
procedures in accordance with professional standards for a review of such
information. However, their separate report dated May 2, 2003 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.
22
ITEM 2. - MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
- --------------------------------------------------------------------------------
OVERVIEW OF CONSOLIDATED BUSINESS
- ---------------------------------
UniSource Energy Corporation (UniSource Energy) is a holding company
that owns substantially all of the outstanding common stock of Tucson
Electric Power Company (TEP), and all of the outstanding common stock of
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. Millennium
invests in unregulated businesses, including a developer of thin-film
batteries, a developer of small-scale commercial satellites, 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 three primary business segments - TEP's Electric
Utility Segment, the Millennium Businesses Segment, and the UniSource Energy
Development Segment.
In October 2002, UniSource Energy entered into two Asset Purchase
Agreements with Citizens Communications Company (Citizens) for the purchase
by UniSource Energy of Citizens' Arizona electric utility and gas utility
businesses for a total of $230 million plus other operating capital
adjustments. The purchase price of each transaction is subject to adjustment
based on the date on which the transaction is closed and, in each case, on
the amount of certain assets and liabilities of the purchased business at the
time of closing. The closing of these transactions is subject to approval by
the Arizona Corporation Commission (ACC), the Federal Energy Regulatory
Commission (FERC) and the Securities and Exchange Commission (SEC). If
completed, these transactions would add to our customer base approximately
77,500 retail electric customers in Arizona, and approximately 122,000 retail
gas customers in Arizona. See Citizens Acquisition below.
Management's Discussion and Analysis explains the results of operations,
the general financial condition, and the outlook for UniSource Energy and its
three primary business segments and includes the following:
- operating results during the first quarter of 2003 compared with the
same period in 2002,
- factors which affect our results and outlook,
- our outlook and strategy, and
- our liquidity, capital needs, capital resources, and contractual
obligations.
TEP is the principal operating subsidiary of UniSource Energy and
accounts for substantially all of its assets and revenues. The seasonal
nature of TEP's business causes operating results to vary significantly from
quarter to quarter. Income and losses from Millennium's unregulated
businesses have had a significant impact on earnings reported by UniSource
Energy for the quarters ended March 31, 2003 and 2002. UED's unregulated
business segment, which was established in February 2001, may have a
significant impact on consolidated net income and cash flows in the future.
In addition, the planned acquisition by UniSource Energy of the Citizens
retail electric and gas utility assets, if completed, will have a significant
impact on our financial condition and results of operations.
Management's Discussion and Analysis should be read in conjunction with
UniSource Energy and TEP's 2002 Form 10-K and with the Condensed Consolidated
Financial Statements, beginning on page 2, which present the results of
operations for the quarters ended March 31, 2003 and 2002. 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. References in this report to the "utility
business" are to TEP.
RESULTS OF OPERATIONS
- ---------------------
UNISOURCE ENERGY CONSOLIDATED
UniSource Energy recorded net income of $53.3 million, or $1.58 per
average share of Common Stock, in the first quarter of 2003, including an
after-tax gain of $67.5 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 Cumulative Effect of Accounting
Change was $14.2 million, or $0.42 per average share of Common Stock. This
compares with a net loss of $6.3 million, or $0.19 per
23
average share of Common Stock, in the first quarter of 2002. The following
factors contributed to the change in income (loss) before the Cumulative Effect
of Accounting Change:
- TEP's purchased power expenses increased by $14 million in the first
quarter of 2003 as a result of additional power purchases and higher power
prices. Power purchases were required to support retail demand at a time
when TEP had scheduled maintenance and major overhauls at several of its
generating stations. Also, because natural gas prices were high, power
purchases were more economical than TEP using its gas generation
facilities.
- Mild winter weather in TEP's service territory contributed to a 1%
decrease in retail revenues.
- A $2.6 million increase in TEP's reserve against receivables from
California wholesale sales and from Enron Corp. (Enron).
- Higher interest expense of $3.3 million related to higher interest
rates under TEP's Credit Agreement, which TEP entered into in November
2002.
- Millennium's after-tax loss was $1.7 million higher in the first
quarter of 2003.
- A $0.6 million decrease in Other Income, which consists of TEP's non-
utility revenue, Millennium's minority interest income, and other
miscellaneous non-utility income.
- A $0.4 million increase in Other Expense, which consists of losses from
Millennium's equity method entities, TEP's charitable donations and
other miscellaneous non-utility expenses.
CONTRIBUTION BY BUSINESS SEGMENT
The table below shows the contributions to our consolidated after-tax
earnings by our three business segments, as well as parent company expenses,
for the first quarter of 2003 and 2002:
Three Months Ended
March 31,
2003 2002
-----------------------------------------------------------------
- Millions of Dollars -
Business Segment
TEP (1) $60.3 $(1.9)
Millennium (5.0) (3.3)
UED (0.1) 0.3
UniSource Energy Standalone (2) (1.9) (1.4)
-----------------------------------------------------------------
Consolidated Net Income (Loss) $53.3 $(6.3)
=================================================================
(1) Includes an after-tax gain of $67.5 million for the Cumulative
Effect of Accounting Change from the adoption of FAS 143 in 2003.
(2) Primarily represents interest expense (net of tax) on the note
payable from UniSource Energy to TEP.
RESULTS OF TEP
The financial condition and results of operations of TEP are currently
the principal factors affecting the financial condition and results of
operations of UniSource Energy on an annual basis. The following discussion
relates to TEP's utility operations, unless otherwise noted. The results of
our unregulated businesses are discussed in Results of Millennium and Results
of UED, below.
Utility kWh Sales and Revenues
------------------------------
Customer growth, weather and other consumption factors affect retail
sales of electricity. Price changes also contribute to changes in retail
revenues. Electric wholesale revenues are affected by market prices in the
wholesale energy market, availability of TEP generating resources, and the
level of wholesale forward contract activity.
24
TEP's electric wholesale sales consist primarily of four types of sales:
(1) Sales under long-term contracts for periods of more than one year.
TEP currently has long-term contracts with three entities to sell
firm capacity and energy: Salt River Project Agricultural
Improvement and Power District (SRP), the Navajo Tribal Utility
Authority and the Tohono O'odham Utility Authority. TEP also has a
multi-year interruptible contract with Phelps Dodge Energy Services,
which requires a fixed contract demand of 60 MW at all times except
during TEP's peak customer energy demand period, from July through
September of each year. Under the contract, TEP can interrupt
delivery of power if the utility experiences significant loss of any
electric generating resources.
(2) Forward contracts to sell energy for periods through the end of the
next calendar year. Under forward contracts, TEP commits to sell a
specified amount of capacity or energy at a specified price over a
given period of time, typically for one-month, three-month or one-
year periods.
(3) Short-term economy energy sales in the daily or hourly markets at
fluctuating spot market prices and other non-firm energy sales.
(4) Sales of transmission service.
Comparisons of TEP's kWh sales delivered and the corresponding electric
revenues for the first quarter of 2003, compared with the same period in 2002,
are shown below:
Sales Operating Revenue
----------------------------------------------------------------------------------------------
Percent Percent
Three Months Ended March 31, 2003 2002 Change 2003 2002 Change
----------------------------------------------------------------------------------------------
- Millions of kWh - - Millions of Dollars -
Electric Retail Sales:
Residential 646 654 (1%) $ 54.6 $ 55.2 (1%)
Commercial 328 325 1% 33.6 33.4 1%
Industrial 470 484 (3%) 32.5 32.7 (1%)
Mining 152 165 (8%) 6.1 6.7 (9%)
Public Authorities 52 53 (2%) 3.7 3.8 (3%)
----------------------------------------------------------------------------------------------
Total Electric Retail Sales 1,648 1,681 (2%) 130.5 131.8 (1%)
----------------------------------------------------------------------------------------------
Electric Wholesale Sales Delivered:
Forward Contracts 180 61 195% 5.6 2.4 133%
Long-term Contracts 329 281 17% 14.2 14.6 (3%)
Short-term Sales and Other 430 549 (22%) 19.1 17.9 7%
Transmission - - - 1.3 0.7 86%
----------------------------------------------------------------------------------------------
Total Electric Wholesale Sales 939 891 5% 40.2 35.6 13%
----------------------------------------------------------------------------------------------
Total 2,587 2,572 1% $170.7 $167.4 2%
==============================================================================================
TEP's average number of retail customers increased by 2.3% to 360,862,
while kWh sales to retail customers decreased by 2% for the first quarter of
2003, compared with the same period in 2002. Kilowatt-hour energy sales
declined in all customer groups, with the exception of sales to commercial
customers, primarily due to milder winter weather. Heating Degree Days
decreased by 19% for the first quarter of 2003 and also decreased 16% when
compared with the 10-year average. Reduced energy sales to TEP's copper
mining customers reflect the continuing cutback in production by one of TEP's
mining customers in response to lower copper prices. Revenue from sales to
retail customers decreased by 1% in 2003, compared with 2002, reflecting the
lower demand.
Electric wholesale sales increased by 5% in the first quarter of 2003,
compared with the same period in 2002, while revenues increased by 13%. The
increase in revenues in the first quarter of 2003 resulted from an increase
in average market prices from those in the first quarter of 2002. Average-
around-the-clock energy prices for the first quarter of 2003 increased to $44
per MWh from $24 per MWh in 2002, primarily due to increased natural gas
prices resulting from low gas storage levels resulting from colder
temperatures in other regions of the U.S. and reduced gas production.
Reduced hydropower supply in the western U.S. also contributed to the higher
market prices. TEP's first quarter 2003 wholesale revenues were reduced by a
$2.2 million reserve for doubtful accounts related to wholesale sales made to
the California Independent System Operator (CISO) and the California Power
Exchange (CPX) in 2001 and 2000. See Payment Defaults and Allowances for
Doubtful Accounts, below.
25
Fuel and Purchased Power Expenses
---------------------------------
Fuel expense at TEP's generating plants decreased by approximately $2
million, or 4%, in the quarter ended March 31, 2003, compared with the same
quarter in 2002, due to maintenance outages at several of its coal-fired
generating stations. Higher natural gas prices in the first quarter of 2003,
compared with the same period in 2002, caused TEP to purchase power in the
wholesale market rather than use its gas generation facilities. The average
cost of fuel per kWh generated for the first quarter of 2003 and the first
quarter of 2002 was 1.92 cents and 1.84 cents, respectively. See Market
Risks - Commodity Price Risk, below.
Purchased Power expense increased $14 million in the first quarter of
2003, compared with the same period in 2002, primarily due to increased
energy purchases to cover scheduled maintenance outages at TEP's coal-fired
facilities. See Other Operating Expenses, below.
Other Operating Expenses
------------------------
Other Operations and Maintenance expense increased by $1 million, or 2%,
in the first quarter of 2003, compared with the same period in 2002.
Maintenance expense increased by $3 million in the first quarter of 2003 due
to scheduled plant maintenance and major overhauls at several of TEP's coal-
fired facilities, including Irvington, San Juan, Four Corners, Navajo and
Springerville Unit 2. Although TEP also had scheduled maintenance at certain
plants in the first quarter of 2002, the outages in 2003 were for more
extended periods at more of TEP's plants. The higher maintenance expense was
partially offset by a $2 million reduction in administrative and general
expense.
Depreciation and amortization expense decreased $3 million, or 8%, in
the first quarter of 2003, compared with the same period in 2002. The
adoption of FAS 143 resulted in a $1.5 million decrease because asset
retirement costs are no longer recorded as a component of depreciation
expense. See Critical Accounting Policies - Accounting for Asset Retirement
Obligations, below.
Other Income (Deductions)
-------------------------
TEP's income statements for the quarters ended March 31, 2003 and 2002
include $3 million and $2 million of Interest Income, respectively, on the
promissory note TEP received from UniSource Energy in exchange for the
transfer of its stock in Millennium. On UniSource Energy's consolidated
income statement, this income is eliminated as an intercompany transaction.
Other Income decreased $0.2 million, offset by a $0.2 million decrease
in Other Expense, in the first quarter of 2003, compared with the same period
in 2002. Other Income includes non-utility revenue, the cost of financing
construction for transmission and distribution projects (AFUDC) attributable
to equity funds, and other miscellaneous non-utility income. Other Expense
includes charitable contributions and other miscellaneous non-utility
expenses.
Interest Expense
----------------
Interest Expense for the first quarter of 2003 increased by
approximately $2 million, compared with the same period in 2002. Letter of
Credit fees under TEP's Credit Agreement were $3 million higher, partially
offset by decreased interest expense on capital leases due to scheduled
repayments and declining principal balances.
Income Tax Expense
------------------
Income tax expense before the Cumulative Effect of Accounting Change
decreased by $4 million in the first quarter of 2003, compared with the same
period in 2002, due to lower pre-tax income.
Cumulative Effect of Accounting Change
--------------------------------------
TEP adopted FAS 143 on January 1, 2003 and recorded a one-time $67.5
million after-tax gain. Upon adoption of FAS 143, TEP recorded an asset
retirement obligation of $38 million at its net present value of $1.1
million, increased depreciable assets by $0.1 million for asset retirement
costs, reversed $112.8 million of costs previously accrued for final removal
from accumulated depreciation, and reversed previously recorded deferred tax
assets of $44.2 million. TEP expects that adopting FAS 143 will result in a
reduction to depreciation expense charged throughout the year as well because
asset retirement costs are no longer recorded as a component of depreciation
expense. For the year 2003, this amount is approximately $6 million. See
Critical Accounting Policies - Accounting for Asset Retirement Obligations.
26
RESULTS OF MILLENNIUM
Millennium's Energy and Technology Investments include Global Solar
Energy, Inc. (Global Solar), Infinite Power Solutions, Inc. (IPS), MicroSat
Systems, Inc. (MicroSat) and ITN Energy Systems, Inc. (ITN). The major
factors contributing to the losses in 2003 and 2002 are development efforts
of solar modules by Global Solar, expenditures to develop thin-film and solid-
state rechargeable batteries by IPS, research and development work performed
by ITN and contract work performed by MicroSat on satellite development.
Other Millennium Investments results include the after-tax operating results
from Millennium Environmental Group, Inc. (MEG), POWERTRUSION International,
Inc. and TruePricing, Inc. (TruePricing). The table below provides a breakdown
of the net losses recorded by Millennium:
Three Months Ended
March 31,
2003 2002
--------------------------------------------------------------------------------------------
- Millions of Dollars -
Energy and Technology Investments
Global Solar and IPS
Research & Development Contract Revenues from Third Parties $ 0.2 $ 0.4
Research & Development Contract Expenses & Losses (1.4) (1.2)
Research & Development - Internal Development Expenses (0.4) (0.6)
Depreciation & Amortization Expense (0.7) (0.8)
Administrative & Other Costs (2.0) (2.4)
Income Tax Benefits 1.7 1.8
--------------------------------------------------------------------------------------------
Total Global Solar and IPS Net Loss (2.6) (2.8)
MicroSat and ITN Energy Systems, Inc. Net Loss (0.7) (0.5)
--------------------------------------------------------------------------------------------
Total Energy and Technology Investments Net Loss (3.3) (3.3)
Other Millennium Investments Net Loss (1.7) -
--------------------------------------------------------------------------------------------
Total Millennium Loss, after-tax $(5.0) $(3.3)
============================================================================================
RESULTS OF UED
UED recorded a net loss of $0.1 million in the first quarter of 2003,
compared with a net profit of $0.3 million in the first quarter of 2002.
UED's loss in 2003 represents operating expenses. UED's income in 2002
represented rental income (less expenses) under an operating lease of a 20 MW
turbine to TEP. The rental income was eliminated from UniSource Energy's
consolidated after-tax earnings as an intercompany transaction. TEP
purchased the turbine from UED in September 2002.
CITIZENS ACQUISITION
- --------------------
Asset Purchase Agreements
-------------------------
On October 29, 2002, UniSource Energy entered into two Asset Purchase
Agreements with Citizens for the purchase by UniSource Energy of Citizens'
Arizona electric utility and gas utility businesses for a total of $230
million in cash. The purchase price of each transaction is subject to
adjustment based on the date the transaction closes and, in each case, on the
amount of certain assets and liabilities of the purchased business at the
time of closing. If the transaction closes before July 28, 2003, the
purchase price is reduced by $10 million. If the transaction closes after
October 29, 2003, the purchase price is increased by $5 million. In
addition, the purchase price in each transaction may also be adjusted if
there is a casualty loss, governmental taking, or discovery of substantial
additional environmental liabilities, in each case subject to materiality
thresholds, prior to the closing. UniSource Energy will assume certain
liabilities associated with the purchased assets, but will not assume
Citizens' obligations under the industrial development revenue bonds issued
to finance certain of the purchased assets for which Citizens will remain the
economic obligor. The asset purchases are expected to close in the second
half of 2003 after the conditions to the consummation of the transactions,
including federal and state regulatory approvals, are satisfied or waived.
The closing of the transactions is subject to approval by the ACC, the
FERC and the SEC under the Public Utility Holding Company Act of 1935, as
amended. As of March 31, 2003, all required filings with the various
governmental authorities have been made and we are still waiting for approval
from the ACC, the FERC and the SEC.
27
The Asset Purchase Agreements are subject to termination if the closing
has not occurred by January 29, 2004 (subject to extension in limited
circumstances), if a governmental authority seeks to prohibit the
transactions, if required regulatory approvals are not obtained with
satisfactory terms and conditions, or if either party is in material breach
and such breach is not cured. If one Asset Purchase Agreement is terminated,
the other will also be automatically terminated. If the Asset Purchase
Agreements are terminated by Citizens due to UniSource Energy's breach,
UniSource Energy must pay to Citizens a $25 million termination fee as
liquidated damages. If the Asset Purchase Agreements are terminated by
UniSource Energy due to Citizens' breach, Citizens must pay to UniSource
Energy a $10 million termination fee as liquidated damages. The termination
fees are also payable in certain other limited circumstances.
We expect that the purchase price will be financed by funds from
UniSource Energy and its affiliates and debt secured by the purchased assets.
TEP is limited by its Credit Agreement, however, as to the amount of
affiliate investments or loans it may make. See Financing Activities -
TEP Credit Agreement, below. TEP must also obtain ACC approval to make a
loan to an affiliate. Various financing alternatives are being discussed
with potential lenders and bridge financing arrangements are being
evaluated. UniSource Energy may also consider financing a portion of the
purchase with new equity, depending on market conditions and other
considerations. If UniSource Energy is unable to obtain financing and
therefore fails to consummate the purchase of these assets, this would
constitute a breach under the contracts and termination damages of $25
million would be payable.
Proposed Settlement Agreement
-----------------------------
Prior to entering into the Asset Purchase Agreements with UniSource
Energy, Citizens had two cases pending before the ACC requesting rate relief
for both the Arizona electric and Arizona gas assets. On April 1, 2003,
UniSource Energy and Citizens reached a proposed settlement agreement
(Citizens Settlement Agreement) with the ACC Staff addressing the rate case
and financing issues. If the ACC approves the Citizens Settlement Agreement,
the changes in rates and financing approvals will take effect once the
acquisition is completed, which is expected to occur by July 2003.
Under the terms of the Citizens Settlement Agreement, UniSource Energy
will form one or more wholly-owned subsidiaries to own and operate the
acquired assets (collectively, the New Companies) and it may also form an
intermediate holding company to finance and own the New Companies.
The Citizens Settlement Agreement includes the resolution of two pending
rate issues before the ACC: (1) a gas utility base rate case and (2) a review
of the electric utility purchase power and fuel adjustment clause. The
Citizens Settlement Agreement provides for a 20.9% increase in gas rates
compared with the 29% increase requested by Citizens. Because UniSource
Energy is acquiring the gas utility assets at a discounted purchase price,
the amount of rate recovery required is less than under the Citizens rate
case. The gas utility rate case also takes into account a $10 million
permanent reduction to the gas rate base due to a disallowance for certain
capital expenditures for gas infrastructure, thereby reducing the revenue
level to be recovered from ratepayers. In addition, the Citizens Settlement
Agreement allows for a 22% increase in electric utility rates, compared with
the 45% requested by Citizens. The allowed electric rate increase represents
the full recovery in rates of the costs of a long-term purchase power
contract on a going forward basis. At the same time, UniSource Energy agreed
to forfeit the collection of approximately $135 million in deferred purchased
power costs under the same contract that had been incurred by Citizens but
had not been collected from Citizens' customers. If the Citizens Settlement
Agreement is approved, the revised electric and gas tariffs would be
effective upon the completion of the acquisition. The Citizens Settlement
Agreement also imposes a general rate case moratorium for a period of three
years from the date the ACC approves the settlement order.
The financing provisions of the Citizens Settlement Agreement authorize
the New Companies to issue new debt and equity securities to fund the
acquisition of the Citizens gas and electric assets and to provide for
initial working capital requirements. The Citizens Settlement Agreement also
authorizes TEP to loan up to $50 million to UniSource Energy to fund the
purchase. In addition, the Citizens Settlement Agreement waives the existing
requirement that 30% of the proceeds of public stock issuance be invested in
TEP, so long as the purpose of the equity issuance is to help finance the
Citizens purchase.
The Citizens Settlement Agreement limits dividends from the New
Companies to 75% of earnings until the ratio of common equity to total
capital reaches 40%. If approved, the Citizens Settlement Agreement would
also modify TEP's dividend limitation. Currently, TEP may not pay dividends
in excess of 75% of its earnings until the ratio of common equity to total
capital reaches 37.5%. Under the Citizens Settlement Agreement, the 75%
earnings payout limitation would remain in effect until TEP's ratio of common
equity to total capital reaches 40%.
28
The Citizens Settlement Agreement is subject to the review and approval
of the ACC and may be amended or supplemented prior to, or in conjunction
with, the approval. The ACC held hearings on the Citizens Settlement
Agreement in early May 2003. UniSource Energy expects that the ACC will act
on the Citizens Settlement Agreement by July 2003.
SPRINGERVILLE GENERATING STATION EXPANSION
- ------------------------------------------
As reported in the 2002 Annual Report on Form 10-K, UED is facilitating
the expansion of the Springerville Generating Station. The Springerville
Generating Station was originally designed for four units. If constructed,
each of Units 3 and 4 would consist of a 400 MW coal-fired, base-load
generating unit at the same site as Springerville Units 1 and 2. If Unit 3
(and subsequently Unit 4) is built, this would allow TEP to spread the fixed
costs of the existing common facilities over the additional generating unit
(or units).
UED currently expects to act as project manager for the development of
Springerville Unit 3 and anticipates that financing and ownership will occur
through third parties. The entire output of Unit 3 is expected to be taken
by regional power companies, including Tri-State Generation and Transmission
Association (Tri-State), SRP, and TEP. UED currently expects that Tri-State
will own 100% of Unit 3 and will take 300 MW of the 400 MW capacity. TEP
would purchase from Tri-State up to 100 MW for no more than five years from
commercial operation. SRP will purchase 100 MW of capacity from Unit 3 under
a 30 year power purchase agreement and will have the right to construct and
own Unit 4 at a later date. If SRP decides to construct Unit 4, TEP would be
required, along with Tri-State, to exercise best efforts to find a replacement
purchaser for SRP to purchase 100 MW of capacity from Unit 3. If unable to
find such a replacement purchaser, TEP would then purchase 100 MW of output
from Unit 4, beginning with the commercial operation of Unit 4.
Tri-State and UED signed a Development Cost Agreement in January 2003 to
each share 50% of the development costs of Unit 3 effective from November 6,
2002 until financial closing. As of March 31, 2003, UniSource Energy had
approximately $23 million of capitalized project development costs on its
balance sheet. Management believes it is probable that UED will proceed with
this project. If the project does not proceed, the capitalized project
development costs will be immediately expensed.
On October 29, 2002, the ACC issued an order that affirms the
Certificate of Environmental Compatibility (CEC) granted to TEP authorizing
the construction of Unit 3, subject to compliance with certain conditions,
and approved the CEC for Unit 4 subject to certain conditions occurring. The
ACC approved construction of a third and fourth unit at the Springerville
Generating Station in 1977 and 1987, respectively, but with respect to Unit
4, the ACC provided that TEP, as plant operator, demonstrate that the fourth
unit was needed to provide an adequate, economical and reliable supply of
electric power to its customers. That demonstration was made as part of the
proceedings that resulted in the issuance of the October 29, 2002 ACC Order.
UED expects to finalize the power purchase agreements, the engineering,
procurement and construction contract, and other required project agreements
during the first half of 2003. UED expects a third party to obtain
construction financing in 2003 and then begin construction. UED expects
commercial operation of Unit 3 to occur in 2006. We can make no assurances,
however, about the ultimate timing, or whether UED will proceed with this
project.
FACTORS AFFECTING RESULTS OF OPERATIONS
- ---------------------------------------
COMPETITION
The electric utility industry has undergone significant regulatory
change in the last few years designed to encourage competition in the sale of
electricity and related services. However, the recent experience in
California with deregulation has caused many states, including Arizona, to
step back and reexamine the viability of retail electric deregulation.
As of January 1, 2001, all of TEP's retail customers are eligible to
choose an alternate energy supplier. 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 have opted to receive 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 include ACC
certification of ESPs, and execution of and compliance with direct access
service agreements with TEP.
29
TEP also 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 TEP's 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.
INDUSTRY RESTRUCTURING
RETAIL
TEP'S Settlement Agreement and Retail Electric Competition Rules
----------------------------------------------------------------
In September 1999, the ACC approved Rules that provided a framework for
the introduction of retail electric competition in Arizona. In November
1999, the ACC approved the Settlement Agreement between TEP and certain
customer groups relating to the implementation of retail electric
competition, including TEP's recovery of its transition recovery assets and
the unbundling of tariffs. During 2002, the ACC reexamined circumstances
that had changed since it approved the Rules in 1999. The outstanding issues
were divided into two groups-"Track A" and "Track B" issues. Track A related
primarily to the divestiture of generation assets while Track B related
primarily to the competitive energy bidding process.
In September 2002, the ACC issued the Track A Order, which eliminated
the requirement in the Settlement Agreement that TEP transfer its generating
assets to a subsidiary. At the same time, the ACC ordered the parties,
including TEP, to develop a competitive bidding process, and reduced the
amount of power to be acquired in the competitive bidding process to only
that portion not supplied by TEP's existing resources.
Recent Developments in the Arizona Regulatory Environment
---------------------------------------------------------
On February 27, 2003, the ACC issued the Track B Order, which defined
the competitive bidding process TEP must use to obtain capacity and energy
requirements beyond what is supplied by TEP's existing resources. For the
period 2003 through 2006, TEP estimates these amounts to be 50,000 MWh of
energy in 2003, or approximately 0.5% of its retail load, gradually
increasing to 104,000 MWh by 2006. The Track B Order further required TEP to
bid out "Economy Energy", or short-term energy purchases, that it estimates
it will make in the 2003 to 2006 period (210,000 to 181,000 MWh).
TEP was also required to bid out its Reliability Must Run (RMR)
generation requirements, which are currently met by its existing local
generation units. TEP's RMR generation requirements are estimated at 471 MW
of capacity and 37,000 MWh of energy in 2003 increasing to 687 MW of capacity
and 38,000 MWh of energy in 2005. TEP does not anticipate that any near-term
RMR requirements will be met through this competitive bidding process because
of the locational and operational requirements of TEP's RMR generation as
well as TEP's belief that its existing RMR generation solutions are
economically sound.
TEP is not required to purchase any power through this process that it
deems to be uneconomical, unreasonable or unreliable. The Track B bidding
process involved the ACC Staff and an independent monitor. The Track B Order
also confirmed that it is not intended to change the current rate-base status
of TEP's existing assets.
In March 2003, TEP issued requests for proposals on its RMR and Economy
Energy requirements. TEP received no RMR bids in its 2003 request for
proposals. TEP received various proposals with respect to its Economy Energy
requirements and, following review, entered into two agreements to meet TEP's
2003 bid requirements under the Track B Order for the period 2003 through
2006 as listed below:
- PPL EnergyPlus, LLC will supply 37 MW June 2003 through December 2003
and 75 MW January 2004 through December 2006 through a unit contingent
contract.
- Panda Gila River LP will supply 50 MW on-peak June through September of
2003 through 2005 through a unit contingent contract.
30
WESTERN ENERGY MARKETS
As a participant in the western U.S. wholesale power markets, TEP is
directly and indirectly affected by changes affecting these markets and
market participants.
Market Prices
-------------
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 average market price for around-the-clock
energy based on the Dow Jones Palo Verde Index increased in 2003 compared
with 2002, as shown below.
Average Market Price for Around-the-Clock Energy MWh
------------------------------------------------------------
Quarter ended March 31, 2003 $44
Quarter ended March 31, 2002 24
------------------------------------------------------------
Average market prices for around-the-clock energy began to rise in
February 2003 due to increased demand and higher natural gas prices resulting
from low gas storage levels resulting from colder temperatures in other
regions of the U.S. and reduced gas production. Reduced hydropower supply in
the western U.S. also contributed to the higher market prices. Starting in
May 2003, the average forward around-the-clock market price for the balance
of the year 2003 is estimated at approximately $46 per MWh, based on forward
market broker quotes as of May 5, 2003. As a result, we expect our wholesale
revenues and purchased power expense to be higher in 2003 than in 2002. 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 2003.
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:
- continued population growth in the western U.S.;
- economic conditions in the western U.S.;
- availability of capacity throughout the western U.S.;
- the extent of electric utility industry restructuring in Arizona,
California and other western states;
- the effect of FERC regulation of wholesale energy markets;
- the availability and price of natural gas;
- precipitation, which affects hydropower availability;
- transmission constraints; and
- environmental restrictions and the cost of compliance.
Payment Defaults and Allowances for Doubtful Accounts
-----------------------------------------------------
California claims that it was overcharged up to $9 billion for wholesale
power purchases in 2000 and 2001, and is seeking refunds from numerous power
generators, including TEP. In early 2001, California's two largest
utilities, Southern California Edison Company (SCE) and Pacific Gas &
Electric Company (PG&E), defaulted on payment obligations owed to various
energy sellers, including the CPX and the CISO. The CPX and the CISO
defaulted on their payment obligations to market participants, including TEP.
While SCE subsequently satisfied its obligations to the CPX, TEP has not
received a corresponding payment from the CPX. The total amount owed to TEP
by the CPX and CISO is $16 million. The FERC has held hearings and FERC
staff has proposed various methodologies for calculating amounts of
refunds/offsets applicable to wholesale sales made into the California spot
markets from October 2000 to June 2001. Based upon the most recent FERC
order in March 2003, TEP estimates that it may receive $6 million of its $16
million receivable. This represents amounts owed to TEP net of TEP's
estimated refund liability. Therefore, in the first quarter of 2003, TEP
increased its allowance for doubtful accounts for its CPX and CISO
receivables by approximately $2 million, from $8 million to $10 million.
In late 2001, Enron filed for bankruptcy protection. At that time, TEP
had an outstanding receivable from Enron of $0.8 million. A recent FERC
order recommended that Enron no longer be allowed to trade and within a few
days thereafter, Enron was delisted from its stock exchange. As a result, in
the first quarter of 2003, TEP increased its allowance for doubtful accounts
for its sales to Enron by $0.4 million, to 100% of its $0.8 million recorded
receivable from Enron.
31
TEP is not able to predict the length and outcome of the FERC hearings
and the outcome of any subsequent lawsuits and appeals that might be filed.
As a participant in the refund proceedings, TEP will be subject to any final
refund orders. TEP does not expect its refund liability, if any, to have a
significant impact on the financial statements. See Critical Accounting
Policies - Payment Defaults and Allowances for Doubtful Accounts, below.
MARKET RISKS
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 2002 Form 10-K.
For additional information concerning risk factors, including market
risks, see Safe Harbor for Forward-Looking Statements below.
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 and the emissions and coal trading activities of
MEG. 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 and MEG's exposure to
commodity price risk, the Risk Management Committee sets trading policies and
limits, which are reviewed frequently to respond to constantly changing
market conditions. To limit TEP and MEG's exposure to credit risk in these
activities, 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.
To manage its exposure to energy price risk, TEP enters into forward
contracts to buy or sell energy at a specified price and future delivery
period. Generally, TEP commits to future sales based on expected excess
generating capability, forward prices and generation costs, using a
diversified market approach to provide a balance between long-term, mid-term
and spot energy sales. TEP enters into forward 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 provide that TEP should
not take a short position in the third quarter and must have owned generation
backing up all forward sales positions at the time the sale is made. TEP's
risk management policies also restrict entering into forward positions with
maturities extending beyond the end of the next calendar year.
The majority of TEP's forward contracts are considered to be "normal
purchases and sales" of electric energy and are not considered to be
derivatives under 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 on a daily basis using actively quoted prices obtained from brokers
for power traded over-the-counter at Palo Verde and at other southwestern
U.S. trading hubs. TEP believes that these broker quotations used to
calculate the mark-to-market values represent accurate measures of the fair
values of TEP's positions, because of the short-term nature of TEP's
positions, as limited by risk management policies, and the liquidity in the
short-term market. When TEP has derivative forward contracts, it uses a
sensitivity analysis to measure the impact of an unfavorable change in market
prices on the fair value of its derivative forward contracts. As of March
31, 2003, all of TEP's derivative forward contracts were for settlement
within twelve months. To adjust the value of its derivative forward
contracts to fair value on its income statement, TEP recorded an unrealized
gain of $0.1 million on its income statement for the quarter ended March 31,
2003, compared with an unrealized gain of $0.8 million on its income
statement for the quarter ended March 31, 2002. This demonstrates the
limited derivative forward contract activity conducted by TEP and the limited
impact on TEP's operating results and financial condition.
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
32
activities, which include 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 2005. As of March 31, 2003 and December 31, 2002, the fair value of
MEG's trading positions combined with Emission Allowances it holds in escrow
was $4.8 million. At the end of the first quarter of 2003, MEG had a $1.7
million unrealized gain and a $2.1 realized loss on its income statement,
compared with an unrealized gain of $0.2 million in the first quarter of 2002.
Unrealized Gain (Loss) of MEG's Trading Activities
- Millions of Dollars -
----------------------------------------------------------
Source of Fair Value Maturity Maturity Maturity over Total Unrealized
At March 31, 2003 0 - 6 mos. 6 - 12 mos. 1 yr. Gain (Loss)
- --------------------------------------------------------------------------------------
Prices actively quoted $ 0.5 $ 0.6 $ 1.3 $ 2.4
Prices provided by other
external sources - - - -
Prices based on models and
other valuation methods (0.7) 0.1 (0.1) (0.7)
- --------------------------------------------------------------------------------------
Total $(0.2) $ 0.7 $ 1.2 $ 1.7
======================================================================================
TEP also purchases coal and natural gas in the normal course of business
to fuel its generating plants. The majority of its coal supplies are
purchased under long-term contracts, which result in very predictable prices.
TEP typically uses its gas generation to meet the summer peak demands of its
firm electric wholesale and retail customers and transmission import
requirements. Due to its limited and historically seasonal usage of natural
gas for firm electric wholesale and retail customers, TEP typically purchases
its gas needs in the spot and short-term markets.
Natural gas prices in the first quarter of 2003, were nearly double
those in the first quarter of 2002, due to low gas storage levels and
reductions in gas production. As a result, TEP decreased use of its gas
generation units in the first quarter of 2003 in favor of more economical
purchases of energy in the wholesale market. In the first quarter of 2003,
TEP's generation output fueled by natural gas was approximately 104,000 MWh,
or 4%, of total generation output, compared with approximately 125,000 MWh, or
5%, of total generation output in the first quarter of 2002.
TEP obtains its gas supply as a retail customer of the local gas
supplier, Southwest Gas Corporation (SWG). TEP periodically negotiates its
contract with its gas supplier to establish terms relating to pricing and
scheduling of gas delivery. SWG is affected by recent FERC actions relating
to its gas allocations from the San Juan and Permian basins. A FERC order is
expected on this issue in the summer of 2003, and at that time, TEP will
renegotiate its gas supply and transportation agreement with SWG. In the
interim, TEP and SWG have agreed on an extension of the current contract
terms through October 31, 2003. TEP does not anticipate any material
difference in operational or economic terms in the new agreement, which is
estimated to begin November 1, 2003.
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 standardized 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 to occur from time to time. 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 March 31, 2003, TEP's total
credit exposure related to its wholesale marketing activities (excluding
defaulted amounts owed by the CPX, the CISO and Enron), was less than $5
million and MEG's total credit exposure related to its trading activities was
$5.5 million. TEP and MEG's credit exposure is diversified across
approximately 30 counterparties. Approximately $1 million of exposure is to
non-investment grade companies.
UniSource Energy is also exposed to credit risk related to the sale of
assets owned by Nations Energy. In September 2001, Nations Energy sold its
26% equity interest in a power project located in Curacao, Netherland
Antilles to a subsidiary of Mirant Corporation (Mirant). Nations Energy
received $5 million in cash and recorded an $11 million note receivable from
the sale at its net present value of $8 million using an 8% discount rate,
with the discount amortized to interest income over the five-year life of the
note. The note is guaranteed by Mirant Americas, Inc., a subsidiary of Mirant.
33
Payments on the note receivable are expected as follows: $2 million in July
2004, $4 million in July 2005, and $5 million in July 2006.
In late 2002 and continuing in 2003, the major rating agencies downgraded
the ratings of Mirant and certain of its subsidiaries citing Mirant's
significantly lower operating cash flow relative to its debt burden coupled
with the likelihood that future operating cash flow levels may weaken further.
Mirant's ratings are now below investment grade. As of March 31, 2003, Nations
Energy's receivable from Mirant is approximately $9 million. We cannot predict
what effect the downgrade of Mirant will have on its ability to make its
required payments to Nations Energy when due, beginning in July 2004. Nations
Energy has not recorded an allowance for doubtful accounts and we will continue
to evaluate the collectibility of the receivable.
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
UNISOURCE ENERGY CONSOLIDATED CASH FLOWS
March 31, March 31,
2003 2002
----------------------------------------------------------
- Millions of Dollars -
Cash Provided by (Used in):
Operating Activities $ 10 $ 9
Investing Activities (34) (128)
Financing Activities (43) (17)
----------------------------------------------------------
Net Decrease in Cash $(67) $136
==========================================================
UniSource Energy's primary source of liquidity is its cash flow from
operations, which is provided primarily from retail and wholesale energy
sales at TEP, net of the related payments for fuel and purchased power.
However, due to the seasonal nature of TEP's business, cash provided by
operating activities varies significantly from quarter to quarter. Cash from
operations is lowest in the first quarter and highest in the third and fourth
quarters due to TEP's summer peaking load. We use our available cash to
finance capital expenditures, primarily at TEP, to make investments in our
energy and technology affiliates, to pay dividends to shareholders, and to
reduce leverage at TEP by repaying high coupon debt and investing in lease
debt.
Net cash flows from operating activities increased by $1 million in the
first quarter of 2003, compared with the same quarter of 2002. Higher
interest received on TEP's investments in Springerville lease debt and lower
income tax payments offset increases in capital lease interest and debt
interest payments in the first quarter of 2003.
Net cash used for investing activities totaled $34 million in the first
quarter of 2003, compared with $128 million during the same period in 2002.
During the first quarter of 2003, construction expenditures were $38 million,
TEP received $9 million in principal payments on its investments in
outstanding Springerville lease debt, and Millennium paid $5 million to fund
its investment in its unconsolidated subsidiaries. In contrast, in the first
quarter of 2002, TEP spent $101 million to purchase and hold outstanding
Springerville lease debt, construction expenditures were $27 million, and
Millennium invested $5 million in its unconsolidated affiliates.
Net cash used in financing activities totaled $43 million in the first
quarter of 2003, compared with $17 million during the same period in 2002.
During the first quarter of 2003, UniSource Energy paid approximately $5
million in dividends to its common shareholders and TEP paid $37 million on
its capital lease obligations. In 2002, UniSource Energy paid approximately
$4 million in dividends to its common shareholders and TEP paid $13 million
on its capital lease obligations. TEP's capital lease payments were higher
in 2003 due to a $28 million scheduled principal payment on the Springerville
Unit 1 lease debt.
Our consolidated cash and cash equivalents decreased to $24 million at
March 31, 2003 from $92 million at March 31, 2002. TEP's cash and cash
equivalents decreased to $10 million at March 31, 2003 compared with $41
million at March 31, 2002. At May 8, 2003, our consolidated cash balance,
including cash equivalents, was approximately $30 million, including TEP's
cash balance of approximately $12 million. 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 2003, we
will adjust our discretionary uses of cash accordingly. We believe, however,
that we will continue to have sufficient cash flow to cover our capital
needs, as well as
34
required debt payments and dividends to shareholders. Furthermore, we believe
that we will have sufficient excess cash flow to continue to make annual
average discretionary debt reductions or lease debt investments at TEP in the
range of $30 - $50 million.
UNISOURCE ENERGY - PARENT COMPANY
Our primary cash needs are to pay dividends to shareholders, to fund
investments in Millennium's unregulated businesses, and to make interest
payments on our promissory note to TEP. In addition, as part of our ACC
Holding Company Order, we must invest at least 30% of any proceeds of equity
issuances in TEP until TEP's equity reaches 37.5% of total capital (excluding
capital leases).
Our primary sources of cash are dividends from TEP. In 2002, TEP paid
dividends to UniSource Energy of $35 million.
In 2003, UniSource Energy will need funds to finance the purchase of the
Citizens Arizona electric and gas utility assets. To finance this purchase,
we plan to issue debt secured by the purchased assets and may also consider
financing a portion of the purchase with new equity, depending on market
conditions and other factors. The Citizens Settlement Agreement waives the
requirement that at least 30% of proceeds of any equity issuance be invested
in TEP, so long as the purpose of the UniSource Energy equity issuance is to
help finance the Citizens asset purchases. We may also borrow up to $50
million from TEP to help finance the purchase, as allowed by the Citizens
Settlement Agreement.
If cash flows fall short of expectations, we may reevaluate the
investment requirements of Millennium's unregulated businesses and/or seek
additional financing for, or investments in, those businesses by unrelated
parties.
TEP - ELECTRIC UTILITY
TEP's capital requirements consist primarily of capital expenditures and
optional and mandatory redemptions of long-term debt and capital lease
obligations.
During 2003, 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, due to the
seasonal nature of TEP's business, cash provided by operating activities
varies significantly from quarter to quarter. At March 31, 2003, TEP had $60
million available under its Revolving Credit Facility. In January 2003, TEP
borrowed $25 million under its Revolving Credit Facility and repaid it within
20 days. On May 1, 2003, TEP borrowed $20 million from this facility, and
expects to repay this borrowing during the second quarter of 2003. If cash
flows fall short of expectations or if monthly cash requirements temporarily
exceed available cash balances, TEP may borrow additional amounts from its
Revolving Credit Facility.
Operating Activities
--------------------
Net cash flows from operating activities increased by $3 million in the
first quarter of 2003, compared with the same quarter of 2002. Higher
interest received on TEP's investments in Springerville lease debt and lower
income taxes paid offset increases in capital lease interest and debt
interest payments in the first quarter of 2003.
Investing Activities
--------------------
Net cash used for investing activities totaled $29 million in the first
quarter of 2003, compared with $123 million during the same period in 2002.
During the first quarter of 2003, TEP spent $37 million for construction
expenditures and received $9 million in principal payments on its investments
in outstanding Springerville lease debt. In contrast, in the first quarter
of 2002, TEP spent $101 million to purchase and hold outstanding
Springerville lease debt and $24 million for construction expenditures.
Capital Expenditures
TEP's capital expenditures for the three months ended March 31, 2003
were $37 million. TEP's forecast for capital expenditures for the year
ending December 31, 2003 is approximately $121 million. These expenditures
include costs for TEP to comply with current federal and state environmental
regulations. Actual construction expenditures may differ from these
estimates due to changes in business conditions, construction schedules,
environmental requirements and changes to our business arising from retail
competition. TEP plans to fund these expenditures through internally-
generated cash flow.
35
Forecasted construction expenditures for 2003 include approximately $10
million for completing a new one mile 500-kV transmission line to enhance
TEP's distribution system link to the regional high voltage transmission
system. In the first quarter of 2003, TEP spent approximately $4 million on
this project and expects the line to be completed prior to June 2003. This
project will provide TEP with greater import capability into TEP's service
area thereby reducing the need to run more expensive local gas generation
during the summer peaking periods.
In January 2001, TEP and Citizens entered into a project development
agreement for the joint construction of a 62-mile transmission line from
Tucson to Nogales, Arizona. In January 2002, the ACC approved the location
and construction of the proposed 345 kV line. Pending federal studies and
approvals for the portion of the line that will pass through a national
forest, construction could begin as early as the third quarter of 2004, with
an expected in-service date at the end of 2005. Construction costs are
expected to be approximately $75 million. TEP has also applied to the U.S.
Department of Energy for a Presidential Permit that would allow building an
extension of the line across the international border with Mexico to
interconnect with Mexico's utility system, providing further reliability and
market opportunities in the region.
Financing Activities
--------------------
Net cash used in financing activities totaled $38 million in the first
quarter of 2003, compared with $14 million during the same period in 2002.
TEP spent $37 million to retire capital lease obligations, compared with $13
million in 2002. Capital lease payments were higher in 2003 due to a $28
million scheduled principal payment on the Springerville Unit 1 lease debt.
TEP Credit Agreement
In November 2002, TEP entered into a new $401 million Credit Agreement
to replace the credit facilities provided under its then existing $441
million credit agreement that would have expired December 30, 2002. The new
agreement consists of a $60 million Revolving Credit Facility and two letter
of credit (LOC) facilities (Tranche A and Tranche B) totaling $341 million.
The Revolving Credit Facility is used to provide liquidity for general
corporate purposes. The LOC Facilities support $329 million aggregate
principal amount of tax-exempt variable rate debt obligations. The Revolving
Credit Facility is a 364-day facility that expires on November 13, 2003. The
Tranche A letters of credit, totaling $135 million, expire in January 2006,
and the Tranche B letters of credit, totaling $206 million, expire in
November 2006.
The new facilities are 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,
mergers and sale-leasebacks. The Credit Agreement also contains several
financial covenants including: (a) 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; however, dividends and
certain investments in affiliates may not exceed 65% of TEP's net income so
long as the Tranche B LOCs are outstanding. The Credit Agreement also
provides that under certain circumstances, certain regulatory actions could
result in a required reduction of the commitments. As of March 31, 2003, TEP
was in compliance with these financial covenants.
In January 2003, TEP borrowed $25 million under its Revolving Credit
Facility and repaid it within 20 days. At March 31, 2003, there were no
outstanding borrowings under this facility. On May 1, 2003, TEP borrowed $20
million under its Revolving Credit Facility and expects to repay this
borrowing during the second quarter of 2003. If TEP encounters temporary
cash needs during the course of the year, it will borrow additional amounts
from its Revolving Credit Facility.
Springerville Common Facilities Leases
In 1985, TEP sold and leased back its undivided one-half ownership
interest in the common facilities at the Springerville Generating Station.
Under the terms of the Springerville Common Facilities Leases, TEP must
periodically refinance or refund the secured notes underlying the leases
prior to the named date in order to avoid a special event of loss. If the
lease debt is not refinanced prior to the special event of loss date
(currently June 30, 2003), the leases would be terminated and TEP would be
required to repurchase the facilities for $125 million.
In January 2003, TEP filed an application with the ACC for authorization
to amend the Springerville Common Facilities Leases and refinance the $70
million of associated lease debt. The interest rate on new lease debt will
be a function of market conditions at the time of refinancing, the lender's
view of TEP's creditworthiness, and the lender's
36
evaluation of the collateral for the secured notes. TEP is in discussions
with several lenders and is considering proposals. As a result of the current
market conditions and a smaller financing market overall, we expect that the
interest rate on the new debt will likely be higher than the current variable
interest rate of LIBOR plus 2.50%, resulting in higher rents payable by TEP.
TEP expects an ACC order approving the refinancing by mid-May and expects to
close prior to June 30, 2003.
MILLENNIUM - UNREGULATED BUSINESSES
Millennium's significant investments, commitments and investment
proceeds for the quarter ended March 31, 2003 are discussed below.
Investments in Energy and Technologies
--------------------------------------
We refer to Global Solar, IPS, MicroSat and ITN as our Energy and
Technology Investments.
- Global Solar - Millennium funded $4 million to Global Solar in the
first quarter of 2003, and $0.8 million in April 2003. Millennium's
unfunded commitment to Global Solar is currently a $5 million line of
credit committed in May 2003. On February 21, 2003, Global Solar
signed a license agreement with ICP Global Technologies, a privately
held Canadian solar product firm. Millennium owns 87% of Global
Solar, but as sole funder recognizes 100% of their losses. Global
Solar has an annual $0.5 million research and development funding
commitment to ITN through 2004.
- IPS - Millennium funded $1 million to IPS in the first quarter of 2003.
Dow Corning Enterprises, Inc. (Dow Corning) funded a corresponding $1
million. In May 2003, Millennium and Dow Corning each funded an
additional $0.5 million. The investments were in exchange for preferred
shares of IPS. Millennium expects to commit an additional $1.5 million to
IPS in the second quarter of 2003. As of March 31, 2003, Millennium owns
approximately 74% of IPS, and for the first quarter of 2003, Millennium
has recorded its ratable share of IPS's losses. Millennium anticipates
it will ultimately own between 59% and 72% of IPS. IPS has a $0.5 million
annual research and development funding commitment to ITN through 2004.
- MicroSat - Millennium owns 49% of MicroSat, but as sole funder recognizes
100% of its losses. Millennium anticipates its ownership of MicroSat
will be reduced to 35% in 2003, based on a 2002 Restructure Agreement.
- ITN - Millennium owns 49% of ITN, but anticipates its ownership will be
reduced to 9% in 2003, based on a 2002 Restructure Agreement.
Millennium, as sole funder, continues to recognize 100% of ITN's losses.
Millennium expects to fund an additional $7 million to $10 million to
these entities during the remainder of 2003. A significant portion of this
funding will be used for research, development and administrative costs and
will be recognized as expense.
Other Millennium Investments and Commitments
--------------------------------------------
Millennium has a $15 million capital commitment to Haddington Energy
Partners II LP (Haddington), a limited partnership which funds energy related
investments. During the first quarter of 2003, Millennium invested
approximately $2 million in Haddington. Millennium has satisfied $8.1
million of the $15 million commitment to date. The remaining $6.9 million is
expected to be funded within the next three years. A member of the UniSource
Energy Board of Directors has an investment in the limited partnership and is
also a managing director of the general partner of the limited partnership.
Millennium has a $6 million capital commitment to a venture capital fund
that will focus on information technology, microelectronics and
biotechnology, primarily within the southwestern U.S. A member of the
UniSource Energy Board of Directors is a general partner of the company that
manages the fund. At March 31, 2003, Millennium had funded approximately $1
million of this commitment. Millennium does not expect to provide any
additional funds to this investment in 2003.
During the first quarter of 2003, Millennium contributed $0.4 million to
TruePricing and agreed to provide up to an additional $0.8 million in future
funding. Following this investment Millennium began accounting for
TruePricing under the consolidation method. Millennium and TEP collectively
now own 51% of the outstanding shares of TruePricing. Previously, Millennium
accounted for TruePricing under the equity method. Millennium, as sole
funder, recognizes 100% of TruePricing's losses, in accordance with GAAP.
37
UED - UNREGULATED ENERGY BUSINESS
UED is responsible as project developer for facilitating the
Springerville Generating Station expansion project construction. If
constructed, each of Units 3 and 4 would consist of a 400 MW coal-fired, base-
load generating unit at the same site as Springerville Units 1 and 2. This
would allow TEP to spread the fixed costs of the existing common facilities
over the additional generating unit (or units). Currently, Tri-State is
expected to own 100% of Unit 3. Upon the completion of construction, TEP
expects to receive annual benefits of approximately $10 million to $15
million in the form of cost savings, rental payments, transmission revenues,
and other fees. TEP will also benefit from upgraded emissions controls for
Units 1 and 2 that will be paid for by the Unit 3 project.
To date, UED has funded approximately $23 million for development of the
project. In January 2003, UED and Tri-State signed a Development Cost
Agreement to each share 50% of the remaining development costs of Unit 3,
effective from November 6, 2002 until financial close. UED expects to
provide an additional $4 million in funding for development prior to Tri-
State obtaining the construction financing. UED expects Tri-State to obtain
construction financing in the third quarter of 2003. We can make no
assurances, however, about the ultimate timing, or whether UED will proceed
with this project.
FINANCING RISKS
UniSource Energy and TEP are exposed to risks related to the ability to
obtain financing at reasonable costs for various projects, agreements to
which they are a party, and their debt obligations. During 2003, UniSource
Energy, TEP and UED will be subject to financing risks and capital market
conditions related to the following:
- UniSource Energy has entered into Asset Purchase Agreements to purchase
the Citizens Arizona electric utility and gas utility assets for $230
million plus operating capital adjustments. UniSource Energy expects
that a portion of the purchase price will be financed with debt secured
by the purchased assets. UniSource Energy may also consider financing a
portion of the purchase price with new equity, depending on market
conditions and other considerations. If UniSource Energy were unable to
obtain financing, and therefore were unable to consummate the purchase
of these assets, this would constitute a breach under the contracts and
termination damages would be payable.
- UED is currently evaluating opportunities to expand the Springerville
Generating Station by assigning the rights to construct Springerville
Units 3 and 4 to unrelated third parties. As of March 31, 2003, UED had
approximately $23 million of capitalized project development costs on
its balance sheet. If a third party does not obtain financing for this
project and as a result, this project does not proceed, the capitalized
project development costs would immediately be expensed.
- TEP must refinance or extend the $70 million of lease debt related to
the Springerville Common Facilities Leases before June 30, 2003. Due to
the ongoing difficult capital market conditions in the energy sector,
TEP will likely be required to pay a higher rate of interest on the new
debt than its existing rate of LIBOR plus 2.5%.
- TEP intends to refinance or extend its 364 day Revolving Credit
Facility, which expires on November 13, 2003.
CONTRACTUAL OBLIGATIONS
There have been no significant changes in our contractual obligations or
other commercial commitments from those reported in our 2002 Annual Report on
Form 10-K, other than those listed below:
- MEG conducts its emissions and coal trading activities using certain
contracts which contain provisions whereby MEG may be required to post
margin collateral due to a change in contract values. As of March 31,
2003, MEG had posted $0.5 million in cash collateral to its trading
counterparties.
- MEG has a $5 million bank line of credit for the purpose of issuing
LOCs to counterparties to support its Emission Allowance and coal
marketing and trading activities. As of March 31, 2003, MEG had
approximately $4 million in outstanding LOCs. This facility expires in
March 2005.
- In May 2003, TEP entered into two purchased power agreements for
periods through 2006 as a result of the competitive bidding process
required by the ACC's Track B order:
38
- PPL EnergyPlus, LLC will supply 37 MW June 2003 through December 2003
and 75 MW January 2004 through December 2006 through a unit
contingent contract.
- Panda Gila River LP will supply 50 MW on-peak June through September
of 2003 through 2005 through a unit contingent contract.
GUARANTEES AND INDEMNITIES
In the normal course of business, UniSource Energy and certain
subsidiaries, including TEP, enter into various agreements providing
financial or performance assurance to third parties on behalf of certain
subsidiaries. These agreements are entered into primarily to support or
enhance the creditworthiness otherwise attributed to a subsidiary on a stand-
alone basis, thereby facilitating the extension of sufficient credit to
accomplish the subsidiaries' intended commercial purposes. The most
significant of these guarantees is Millennium's guarantee of approximately
$3.5 million in commodity-related payments for MEG at March 31, 2003. 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 UniSource Energy or TEP would be required
to perform or otherwise incur any significant losses associated with any of
these guarantees is remote.
DIVIDENDS ON COMMON STOCK
UniSource Energy
----------------
In February 2003, UniSource Energy declared a cash dividend of $0.15 per
share on its Common Stock. This dividend, totaling approximately $5 million,
was paid March 7, 2003 to shareholders of record at the close of business on
February 21, 2003.
UniSource Energy's Board of Directors will review our dividend level on
a continuing basis, taking into consideration a number of factors including
our results of operations and financial condition, general economic and
competitive conditions and the cash flow from our subsidiary companies, TEP,
Millennium and UED.
TEP
---
In 2002, TEP declared and paid dividends of $35 million. UniSource
Energy is the primary holder of TEP's 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 March 31, 2003, the
required minimum net worth was $298 million. TEP's actual net worth at March
31, 2003 was $398 million, and was $368 million as defined in the Credit
Agreement. As of March 31, 2003, TEP was in compliance with the terms of the
Credit Agreement. Under the terms of the Credit Agreement, dividends and
certain investments in affiliates may not exceed 65% of TEP's net income for
the immediately preceding fiscal year, so long as the Tranche B LOCs are
outstanding. See Financing Activities - TEP Credit Agreement, above.
The ACC Holding Company Order states that TEP may not pay dividends to
UniSource Energy in excess of 75% of its earnings until TEP's common equity
equals 37.5% of total capital (excluding capital lease obligations). As of
March 31, 2003, TEP's equity ratio on that basis was 26%. If the Citizens
Settlement Agreement is approved by the ACC, this dividend limitation will
remain in place until TEP's equity ratio equals 40%.
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.
Therefore, TEP declared its December 2002 dividend from 2002 earnings since
TEP had an accumulated deficit, rather than positive retained earnings.
39
Millennium and UED
------------------
Millennium did not pay any dividends to UniSource Energy in 2002. We
cannot predict the amount or timing of future dividends from Millennium. UED
has not paid any dividends to UniSource Energy.
OUTLOOK 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:
- Complete the acquisition of the Arizona electric utility and gas
utility assets from Citizens described above.
- Facilitate the construction of Springerville Unit 3, which will allow
TEP to spread the fixed costs of its Springerville Units 1 and 2 Common
Facilities over an additional unit.
- 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 completing a new
one mile 500-kV line to enhance TEP's distribution system's link to the
regional high voltage transmission system.
- Improve production of Global Solar's thin-film photovoltaic cells and
seek strategic partners.
- Reduce TEP's debt as appropriate, using some of our excess cash flows.
Although no specific retirements are planned at this time, TEP expects
to use $30 million to $50 million annually for debt reductions or lease
debt investments.
- Efficiently manage TEP's generating resources and look for ways to
reduce or control our operating expenses in order to improve
profitability.
To accomplish our goals, we estimate that during 2003, TEP will spend
$121 million on capital expenditures, Millennium will provide between $12
million and $15 million of funding to its Energy and Technology Investments,
and we will provide between $4 million and $6 million in funding to UED. Our
funding to UED will depend upon the timing of the financial close of the
Springerville expansion project. In addition, we plan to pay $230 million
plus operating capital adjustments for the acquisition of the Arizona
electric utility and gas utility assets from Citizens.
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.
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 2002 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 generally uses 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), issued by
the Financial Accounting Standards Board (FASB), require special accounting
treatment for regulated companies to show the effect of regulation. For
example, in setting TEP's retail rates, the ACC may not allow TEP to
currently charge its 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 defer these items and show them as
regulatory assets on the balance sheet until TEP is allowed to charge its
customers. TEP then amortizes these items as expense to the income statement
as those charges are
40
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:
- an independent regulator sets rates;
- the regulator sets the rates to recover specific costs of delivering
service; and
- the service territory lacks competitive pressures to reduce rates below
the rates set by the regulator.
In November 1999, upon approval by the ACC of TEP's Settlement Agreement
relating to recovery of TEP's transition costs and standard retail rates, TEP
discontinued application of FAS 71 to its generation operations.
TEP's regulatory assets total $381 million at March 31, 2003, $22
million of which are not presently included in the rate base and consequently
are not earning a return on investment.
TEP continues to apply FAS 71 to the distribution and transmission
portions of its business, its regulated operations, and continues to assess
whether it can continue to apply FAS 71 to these operations. If TEP stopped
applying FAS 71 to its remaining regulated operations, it would write off the
related balances of its regulatory assets as an expense on its income
statement. Based on the balances of TEP's regulatory assets at March 31,
2003, if TEP had stopped applying FAS 71 to its remaining regulated
operations, it would have recorded an extraordinary loss, after-tax, of
approximately $230 million. While regulatory orders and market conditions
may affect TEP's cash flows, its cash flows would not be affected if it
stopped applying FAS 71 unless a regulatory order limited its ability to
recover the cost of that regulatory asset.
ACCOUNTING FOR ASSET RETIREMENT OBLIGATIONS
FAS 143, issued by the FASB in June 2001, requires entities to record
the fair value of a liability for a legal obligation to retire an asset in
the period in which the liability is incurred. A legal obligation is a
liability that a party is required to settle as a result of an existing or
enacted law, statute, ordinance or contract. When the liability is initially
recorded, the entity should capitalize a cost by increasing the carrying
amount of the related long-lived asset. Over time, the liability is adjusted
to its present value by recognizing accretion expense as an operating expense
in the income statement each period, and the capitalized cost is depreciated
over the useful life of the related asset. Upon settlement of the liability,
an entity either settles the obligation for its recorded amount or incurs a
gain or loss if the actual costs differ from the recorded amount.
Prior to adopting FAS 143, costs for final removal of all owned
generation facilities were accrued as an additional component of depreciation
expense. Under FAS 143, only the costs to remove an asset with legally
binding retirement obligations will be accrued over time through accretion of
the asset retirement obligation and depreciation of the capitalized asset
retirement cost.
TEP has identified legal obligations to retire generation plant assets
specified in land leases for its jointly-owned Navajo and Four Corners
Generating Stations. The land on which the Navajo and Four Corners
Generating Stations reside is leased from the Navajo Nation. The provisions
of the leases require the lessees to remove the facilities upon request of
the Navajo Nation at the expiration of the leases. TEP also has certain
environmental obligations at the San Juan Generating Station. TEP has
estimated that its share of the cost to remove the Navajo and Four Corners
facilities and settle the San Juan environmental obligations is approximately
$38 million at the date of retirement. No other legal obligations to retire
generation plant assets were identified. Millennium and UED have no asset
retirement obligations.
TEP has various transmission and distribution lines that operate under
land leases and rights of way that contain end dates and restorative clauses.
TEP operates its transmission and distribution lines as if they will be
operated in perpetuity and would continue to be used or sold without land
remediation. As a result, TEP will not recognize the costs of final removal
of the transmission and distribution lines in the financial statements.
Upon adoption of FAS 143 on January 1, 2003, TEP recorded an asset
retirement obligation of $38 million at its net present value of $1.1
million, increased depreciable assets by $0.1 million for asset retirement
costs, reversed $112.8 million of costs previously accrued for final removal
from accumulated depreciation, reversed previously recorded deferred tax
assets by $44.2 million and recognized the cumulative effect of accounting
change as a gain of $111.7 million ($67.5 million net of tax). TEP expects
that adopting FAS 143 will result in a reduction to current depreciation
expense charged throughout the year as well because asset retirement costs
are no longer recorded as a component of depreciation expense. For the year
2003, this amount is approximately $6 million.
41
Amounts recorded under FAS 143 are subject to various assumptions and
determinations, such as determining whether a legal obligation exists to
remove assets, estimating the fair value of the costs of removal, estimating
when final removal will occur, and the credit-adjusted risk-free interest
rates to be used to discount future liabilities. Changes that may arise over
time with regard to these assumptions and determinations will change amounts
recorded in the future as expense for asset retirement obligations.
If TEP retires any asset at the end of its useful life, without a legal
obligation to do so, it will record retirement costs at that time as incurred
or accrued. TEP does not believe that the adoption of FAS 143 will result in
any change in retail rates since all matters relating to the rate-making
treatment of TEP's generating assets have been determined pursuant to the
Settlement Agreement.
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. Prior to 2003 and since December 31, 2001,
TEP had an allowance for doubtful accounts recorded for $8 million, or 50% of
these uncollected amounts based on the amount TEP believed would be
collected. In the first quarter of 2003, as a result of a recent FERC order,
TEP estimated that $6 million of its $16 million receivable will be
collected. Therefore, in the first quarter of 2003, TEP increased its
reserve by $2.2 million by recording a reduction of wholesale revenues. The
amount that TEP ultimately collects would have an impact on earnings if the
amount is more or less than the $10 million TEP has reserved. If TEP
collects all of the $16 million, pre-tax income will increase by $10 million.
If TEP does not collect any of the $16 million, pre-tax income will decrease
by $6 million. TEP also believes that it is due interest on the amounts TEP
is owed, but TEP has not recorded such interest. 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.
Additionally, a recent FERC order recommended that Enron no longer be
allowed to trade and within a few days thereafter, Enron was delisted from
its stock exchange. As a result, in the first quarter of 2003, TEP increased
its reserve for sales to Enron by $0.4 million, to 100% of its $0.8 million
recorded receivable from Enron. At March 31, 2003 and December 31, 2002,
TEP's reserve for electric wholesale accounts receivable on its balance sheet
was approximately $11 million and $8 million, respectively.
CAPITALIZATION OF UED PROJECT DEVELOPMENT COSTS
UED capitalizes project development costs when it is probable that the
project will be completed and it expects to recover the costs of the project.
At March 31, 2003, capitalized project development costs on UniSource
Energy's balance sheet were approximately $23 million. If the Springerville
expansion project does not proceed, the capitalized project development costs
will be immediately expensed.
PENSION AND OTHER POSTRETIREMENT BENEFIT PLAN ASSUMPTIONS
TEP records plan assets, obligations, and expenses, related to its
pension and other postretirement benefit plans based on actuarial valuations.
These valuations include key assumptions on: discounts 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. TEP believes that the assumptions used in recording
obligations under the plans are reasonable based on prior experience, market
conditions and from the advice of plan actuaries.
TEP discounted its future pension and other postretirement plan
obligations using a rate of 6.75% at December 31, 2002, compared to 7.25% at
December 31, 2001. TEP determines the discount 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. 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
42
offset to some degree by a larger obligation. The relative magnitude of these
two changes determines whether interest cost will increase or decrease. TEP's
interest cost increased slightly as a result of the decrease in the discount
rate. For TEP's pension plans, a 25 basis point decrease in the discount rate
would increase the accumulated benefit obligation by approximately $3.7 million
and the related plan expense for 2003 by approximately $0.6 million. A similar
increase in the discount rate would decrease the accumulated benefit obligation
by approximately $3.5 million and the related plan expense for 2003 by
approximately $0.6 million. For TEP's plan for other postretirement benefits,
a 25 basis point decrease in the discount rate would increase the accumulated
benefit obligation by approximately $1.5 million and the related plan expense
for 2003 by approximately $0.1 million. A similar increase in the discount
rate would decrease the accumulated benefit obligation by approximately $1.5
million and the related plan expense for 2003 by approximately $0.1 million.
TEP calculates the market-related value of plan assets using the fair
value of plan assets on the measurement date. At December 31, 2002, TEP
assumed that its plans' assets would generate a long-term rate of return of
8.75%. This rate is lower than the assumed rate of 9.0% used at December 31,
2001. 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 the plans' actuaries
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 decrease in the expected
return on plan assets would increase pension expense for 2003 by
approximately $0.3 million. A similar increase in the expected return on
plan assets would decrease pension expense for 2003 by approximately $0.3
million.
In recognition of significant increases in health care costs, TEP
increased the initial health care cost trend rate used in valuing its
postretirement benefit obligation to 12.0% at December 31, 2002. The rate
assumed at December 31, 2001 was 8.5%. Assumed health care cost trend rates
have a significant effect on the amounts reported for health care plans. A
one percentage-point increase in assumed health care cost trend rates would
increase the postretirement benefit obligation by approximately $5 million
and the related plan expense by approximately $1 million. A similar decrease
in assumed health care cost trend rates would decrease the postretirement
benefit obligation by approximately $4 million and the related plan expense
by approximately $1 million.
As reported in the 2002 Annual Report on Form 10-K, TEP recorded a
minimum pension liability of $6.7 million at December 31, 2002 primarily
because of current stock market conditions and a reduction in the assumed
discount rate.
Based on the above assumptions, TEP will record pension expense of $8.5
million and other postretirement benefit expense of $6.6 million ratably
throughout 2003. TEP will make required pension plan contributions of $2.8
million in 2003. TEP's other postretirement benefit plan is not funded. TEP
expects to make benefit payments to retirees under the postretirement benefit
plan of approximately $2 million in 2003.
ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND TRADING ACTIVITIES
A derivative financial instrument or other contract derives its value
from another investment or designated benchmark. TEP enters into forward
contracts to purchase or sell a specified amount of capacity or energy at a
specified price over a given period of time, typically for one month, three
months, or one year, within established limits to take advantage of favorable
market opportunities. The majority of TEP's forward contracts are considered
normal purchases and sales under FAS 133 and, therefore, are not required to
be marked to market. However, some of these forward contracts are considered
to be derivatives, which TEP marks to market under FAS 133 by recording
unrealized gains and losses and adjusting the related assets and liabilities
on a monthly basis to reflect the market prices at the end of the month. TEP
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 may change the
conclusions that it has reached and, as a result, the accounting treatment
and financial statement impact could change in the future.
MEG enters into swap agreements, options and forward contracts relating
to Emission Allowances and coal. MEG also marks its trading contracts to
market under FAS 133 by recording unrealized gains and losses on its trading
activities and adjusting the related assets and liabilities on a monthly
basis to reflect the market prices at the end of the month.
43
The market prices used to determine fair value for TEP and MEG's
derivative instruments are estimated based on various factors including
broker quotes, exchange prices, over the counter prices and time value. TEP
reports its unrealized gain/loss on derivative forward sales net of its
unrealized gain/loss on derivative forward purchases as a component of
Operating Revenues. MEG reports its unrealized gain/loss on trading
activities net of its realized gain/loss on trading activities as a component
of Operating Revenues. The net pre-tax loss on TEP forward contracts and MEG
trading activities for the three months ended March 31, 2003, was $0.3
million. At March 31, 2003, the fair value of TEP's derivative assets was
$0.1 million and is included in Other Current Assets. At March 31, 2003, the
fair value of MEG's trading assets, including MEG's Emission Allowance
inventory, was $22.9 million, which is reported in Current Assets, and the
fair value of MEG's trading liabilities was $18.0 million, which is reported
in Current Liabilities.
See Market Risks - Commodity Price Risk, above.
UNBILLED REVENUE
TEP's electric retail revenues include an estimate of MWhs delivered but
unbilled at the end of each period. The unbilled revenue is estimated by
comparing the actual MWhs consumed to the MWhs billed to our retail
customers. The excess of MWhs consumed over MWhs billed is then allocated to
the retail customer classes based on estimated usage by each customer class.
TEP then records 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 is greater in the summer months than
it is in the winter months.
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.
The valuation allowance of $16 million at March 31, 2003, which reduces
the Deferred Tax Asset balance, relates to net operating loss and investment
tax credit carryforward amounts. In the future, if TEP determines that TEP
would be able to use all or a portion of these amounts on tax returns, then
TEP would reduce the reserve and recognize a tax benefit up to $16 million.
Factors that could cause TEP to recognize the tax benefit include new or
additional guidance through tax regulations, tax rulings, case law and/or the
use of such benefits on future tax returns.
NEW ACCOUNTING PRONOUNCEMENTS
- -----------------------------
The FASB recently issued the following Statement of Financial Accounting
Standards (FAS) and FASB Interpretations (FIN):
- FIN 45, Guarantor's Accounting and Disclosure Requirements for
Guarantees, Including Indirect Guarantees of Indebtedness of Others,
issued November 2002, requires disclosures to be made by a guarantor in
its interim and annual financial statements about its obligations under
certain guarantees that it has issued. FIN 45 also clarifies that a
guarantor is required to recognize, at the inception of a guarantee, a
liability for the fair value of the obligation undertaken in issuing the
guarantee. The initial recognition and initial measurement provisions
of FIN 45 are applicable on a prospective basis to guarantees issued or
modified beginning January 1, 2003. The disclosure requirements of FIN
45 are immediately effective. See Guarantees and Indemnities in Note 9.
- FIN 46, Consolidation of Variable Interest Entities, issued January
2003, expands upon existing guidance that addresses when a company
should include in its financial statements the assets and liabilities of
another entity. The primary objectives of FIN 46 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 enterprise should
consolidate the variable interest entity (primary beneficiary). FIN 46
requires that both the primary beneficiary and all other enterprises
with a significant variable interest make additional disclosures. The
transitional disclosure requirements of FIN 46 are effective
immediately. The effective date of the consolidation requirements of
FIN 46 depends on the date the variable interest entity was created.
FIN 46 is effective for all variable interest entities created after
January 31, 2003. For variable interest entities created before
February 1, 2003, the provisions of FIN 46 are to be applied to a
variable interest entity for interim reporting periods beginning after
June 30, 2003. UniSource Energy's investments in MicroSat and ITN are
44
accounted for under the equity method (see Note 8). UniSource Energy is
the primary funding source for these investments and recognizes all of
the losses. UniSource Energy may be required to consolidate MicroSat
and ITN beginning July 1, 2003. The consolidation of MicroSat and ITN
would not have a material impact on UniSource Energy's financial
statements, as these entities do not presently have significant assets
or debt from outside third parties.
- FAS 149, Amendment of Statement 133 on Derivative Instruments and
Hedging Activities, was issued by the FASB in April 2003. FAS 149
amends and clarifies accounting for derivative instruments, including
certain derivative instruments embedded in other contracts, and for
hedging activities under FAS 133. FAS 149 is effective for contracts
entered into or modified after June 30, 2003, except as stated below,
and for hedging relationships designated after June 30, 2003. The
guidance should be applied prospectively. The provisions of FAS 149
that relate to FAS 133 Implementation Issues that have been effective
for fiscal quarters that began prior to June 15, 2003, should continue
to be applied in accordance with their respective effective dates. Due
to TEP and MEG's limited amount of derivative activity, we do not expect
the adoption of FAS 149 to have a significant effect on UniSource Energy
or TEP's financial statements.
SAFE HARBOR FOR FORWARD-LOOKING STATEMENTS
- ------------------------------------------
This Quarterly Report on Form 10-Q contains forward-looking statements
as defined by the Private Securities Litigation Reform Act of 1995.
UniSource Energy and TEP are including the following cautionary statements to
make applicable and take advantage of the safe harbor provisions of the
Private Securities Litigation Reform Act of 1995 for any forward-looking
statements made by or for UniSource Energy or TEP in this Quarterly Report on
Form 10-Q. Forward-looking statements include statements concerning plans,
objectives, goals, strategies, future events or performance and underlying
assumptions and other statements that are not statements of historical facts.
Forward-looking statements may be identified by the use of words such as
"anticipates," "estimates," "expects," "intends," "plans," "predicts,"
"projects," and similar expressions. From time to time, we may publish or
otherwise make available forward-looking statements of this nature. All such
forward-looking statements, whether written or oral, and whether made by or
on behalf of UniSource Energy or TEP, are expressly qualified by these
cautionary statements and any other cautionary statements which may accompany
the forward-looking statements. In addition, UniSource Energy and TEP
disclaim any obligation to update any forward-looking statements to reflect
events or circumstances after the date of this report.
Forward-looking statements involve risks and uncertainties that 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 TEP's retail service area.
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 restrictions and cost of compliance, and FERC
regulation of wholesale energy markets, and economic conditions in
the western U.S.
5. The creditworthiness of the entities with which UniSource Energy,
TEP, Millennium and their affiliates transact business or have
transacted business.
6. Changes affecting TEP's 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.
45
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 UniSource Energy or TEP.
10. Market conditions and technological changes affecting UniSource
Energy's unregulated businesses.
11. Regulatory conditions to the approval of the acquisition of
Citizens' Arizona electric and gas utility assets.
12. The level of rate relief granted with respect to Citizens' Arizona
electric utility and gas utility assets.
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. Whether the proposed Springerville Generating Station expansion
proceeds; the role of Tri-State, SRP, and other third parties in
such expansion; and the ultimate terms of the ownership, operating
and power purchase arrangements.
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,
2002, in addition to the interim condensed consolidated financial statements
and accompanying notes presented in Items 1 and 2 of this Form 10-Q.
See Item 2- Management's Discussion and Analysis of Financial Condition
and Results of Operations, Factors Affecting Results of Operations, Market
Risks.
ITEM 4. - CONTROLS AND PROCEDURES
- --------------------------------------------------------------------------------
UniSource Energy and TEP have disclosure controls and procedures to
ensure that material information contained in their filings with the SEC is
recorded, processed, summarized and reported on an accurate and timely basis.
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-14(c) and 15d-14(c) under the Securities Exchange Act of
1934, as amended, within 90 days prior to the filing of this report. Based
on such evaluation, the principal executive officer and principal financial
officer of UniSource Energy and TEP have concluded that such disclosure
controls and procedures are 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. Since such evaluation
there have not been any significant changes in UniSource Energy and TEP's
internal controls, or in other factors that could significantly affect these
controls.
46
PART II - OTHER INFORMATION
ITEM 1. - LEGAL PROCEEDINGS
- --------------------------------------------------------------------------------
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 Springerville Generating Station to
the Superior Court of the State of Arizona.
Additionally, 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 and that new permits and the
installation of additional facilities meeting Best Available Control
Technology standards are required for the continued operation of Units 1 and
2 in accordance with applicable law. 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. TEP believes these
claims are without merit and will vigorously contest them.
Litigation Related to San Juan Coal Company
-------------------------------------------
On July 30, 2002, Dugan Production Corp. (Dugan) filed a lawsuit against
the San Juan Coal Company, the coal supplier to the San Juan Generating
Station (San Juan). TEP owns 50% of San Juan Units 1 and 2, which equates to
19.8% of San Juan in total. The San Juan Coal Company, through leases with
the federal government and the State of New Mexico, owns coal interests with
respect to an underground mine. Dugan, through leases with the federal
government, the State of New Mexico and certain private parties, claims to
own certain oil and gas interests in portions of the land used for the
underground mine. Dugan alleges that San Juan Coal Company's underground
coal mining operations have or will interfere with Dugan's gas production and
will reduce the amount of natural gas that Dugan would otherwise be entitled
to recover. Dugan seeks a declaration by the court that the rights under its
leases are senior and superior to the rights of the San Juan Coal Company and
seeks to prohibit the underground mining of coal from a portion of the land
used for the underground mine as described above. Dugan also seeks monetary
damages.
The San Juan Coal Company has informed Public Service Company of New
Mexico (PNM) that it intends to strongly dispute the litigation. TEP cannot
predict the ultimate outcome of this litigation, or whether it will adversely
affect the amount of coal available or cost of coal to San Juan. TEP does
not expect resolution of this litigation to be material to TEP as a 19.8%
owner of San Juan.
Litigation 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 PNM
as operator of San Juan. The lawsuit, which alleges two violations of the
Clean Air Act and related regulations and permits, seeks penalties as well as
injunctive and declaratory relief and is presently scheduled for trial in the
third quarter of 2003. Based on its investigation to date, PNM has stated
that it firmly believes that the allegations are without merit, and vigorously
disputes the allegations. Only one of those allegations relates to a unit in
which TEP owns an interest. While TEP is unable to predict the ultimate outcome
of the lawsuit, TEP does not believe the outcome will be material to TEP.
47
ITEM 5. - OTHER INFORMATION
- --------------------------------------------------------------------------------
ADDITIONAL FINANCIAL DATA
The following table reflects the ratio of earnings to fixed charges for
TEP:
3 Months Ended 12 Months Ended
March 31, March 31,
2003 2003
---- ----
Ratio of Earnings to Fixed Charges 0.73% * 1.51%
* The Ratio of Earnings to Fixed Charges for the 3 months ended March 31,
2003 is less than one-to-one coverage as a result of the seasonal nature of
TEP's business. In the first quarter of 2003, TEP incurred a net loss of
$7.2 million, exclusive of a one time $67.5 million Cumulative Effect of
Accounting Change, of which $10.7 million represents the amount of the
deficiency needed to attain a one-to-one coverage.
APPROVAL OF NON-AUDIT SERVICES
On April 24, 2003 the Audit Committee of the Board of Directors of
UniSource Energy pre-approved an increase in the dollar amount to $350,000
for PricewaterhouseCoopers LLP to perform audit related services of the gas
and electric asset balances and results of operations therefore for Citizens
Utilities, Inc., located in Arizona.
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 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.
- UniSource Energy and TEP Form 8-K, dated April 14, 2003 regarding a
proposed Settlement Agreement with ACC Staff addressing rate case
and financing issues in the planned acquisition by UniSource Energy
of the Citizens Arizona gas and electric assets.
- UniSource Energy and TEP Form 8-K, dated April 28, 2003 furnished
pursuant to Item 12 "Disclosure of Results of Operations and
Financial Condition", announcing first quarter 2003 earnings for
UniSource Energy and TEP.
48
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 subsidiary.
UNISOURCE ENERGY CORPORATION
----------------------------
(Registrant)
Date: May 15, 2003 /s/ Kevin P. Larson
----------------------------
Kevin P. Larson
Vice President and Principal
Financial Officer
TUCSON ELECTRIC POWER COMPANY
-----------------------------
(Registrant)
Date: May 15, 2003 /s/ Kevin P. Larson
-----------------------------
Kevin P. Larson
Vice President and Principal
Financial Officer
49
CERTIFICATION
Pursuant to Section 302 of the Sarbanes-Oxley Act
I, James S. Pignatelli, certify that:
1. I have reviewed this quarterly report on Form 10-Q of UniSource Energy
Corporation;
2. Based on my knowledge, this quarterly report does not contain any untrue
statement of a material fact or omit to state a material fact necessary
to make the statements made, in light of the circumstances under which
such statements were made, not misleading with respect to the period
covered by this quarterly report;
3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and
cash flows of the registrant as of, and for, the periods presented in
this quarterly report;
4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as
defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant
and we have:
a. designed such disclosure controls and procedures to ensure that
material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within
those entities, particularly during the period in which this
quarterly report is being prepared;
b. evaluated the effectiveness of the registrant's disclosure
controls and procedures as of a date within 90 days prior to the
filing date of this quarterly report (the "Evaluation Date"); and
c. presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls and procedures based on
our evaluation as of the Evaluation Date;
5. The registrant's other certifying officers and I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the
audit committee of registrant's board of directors (or persons performing
the equivalent function):
a. all significant deficiencies in the design or operation of internal
controls which could adversely affect the registrant's ability to
record, process, summarize and report financial data and have
identified for the registrant's auditors any material weaknesses in
internal controls; and
b. any fraud, whether or not material, that involves management or
other employees who have a significant role in the registrant's
internal controls; and
6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in
internal controls or in other factors that could significantly affect
internal controls subsequent to the date of our most recent evaluation,
including any corrective actions with regard to significant deficiencies
and material weaknesses.
Date: May 15, 2003 /s/ James S. Pignatelli
----------------------------------------------
James S. Pignatelli
Chairman, President, and
Chief Executive Officer
50
CERTIFICATION
Pursuant to Section 302 of the Sarbanes-Oxley Act
I, Kevin P. Larson, certify that:
1. I have reviewed this quarterly report on Form 10-Q of UniSource Energy
Corporation;
2. Based on my knowledge, this quarterly report does not contain any untrue
statement of a material fact or omit to state a material fact necessary
to make the statements made, in light of the circumstances under which
such statements were made, not misleading with respect to the period
covered by this quarterly report;
3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and
cash flows of the registrant as of, and for, the periods presented in
this quarterly report;
4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as
defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant
and we have:
a. designed such disclosure controls and procedures to ensure that
material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within
those entities, particularly during the period in which this
quarterly report is being prepared;
b. evaluated the effectiveness of the registrant's disclosure
controls and procedures as of a date within 90 days prior to the
filing date of this quarterly report (the "Evaluation Date"); and
c. presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls and procedures based on
our evaluation as of the Evaluation Date;
5. The registrant's other certifying officers and I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the
audit committee of registrant's board of directors (or persons performing
the equivalent function):
a. all significant deficiencies in the design or operation of internal
controls which could adversely affect the registrant's ability to
record, process, summarize and report financial data and have
identified for the registrant's auditors any material weaknesses in
internal controls; and
b. any fraud, whether or not material, that involves management or
other employees who have a significant role in the registrant's
internal controls; and
6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in
internal controls or in other factors that could significantly affect
internal controls subsequent to the date of our most recent evaluation,
including any corrective actions with regard to significant deficiencies
and material weaknesses.
Date: May 15, 2003 /s/ Kevin P. Larson
----------------------------------------------
Kevin P. Larson
Vice President, Chief Financial Officer
and Treasurer
51
CERTIFICATION
Pursuant to Section 302 of the Sarbanes-Oxley Act
I, James S. Pignatelli, certify that:
1. I have reviewed this quarterly report on Form 10-Q of Tucson Electric
Power Company;
2. Based on my knowledge, this quarterly report does not contain any untrue
statement of a material fact or omit to state a material fact necessary
to make the statements made, in light of the circumstances under which
such statements were made, not misleading with respect to the period
covered by this quarterly report;
3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and
cash flows of the registrant as of, and for, the periods presented in
this quarterly report;
4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as
defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant
and we have:
a. designed such disclosure controls and procedures to ensure that
material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within
those entities, particularly during the period in which this
quarterly report is being prepared;
b. evaluated the effectiveness of the registrant's disclosure
controls and procedures as of a date within 90 days prior to the
filing date of this quarterly report (the "Evaluation Date"); and
c. presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls and procedures based on
our evaluation as of the Evaluation Date;
5. The registrant's other certifying officers and I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the
audit committee of registrant's board of directors (or persons performing
the equivalent function):
a. all significant deficiencies in the design or operation of internal
controls which could adversely affect the registrant's ability to
record, process, summarize and report financial data and have
identified for the registrant's auditors any material weaknesses in
internal controls; and
b. any fraud, whether or not material, that involves management or
other employees who have a significant role in the registrant's
internal controls; and
6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in
internal controls or in other factors that could significantly affect
internal controls subsequent to the date of our most recent evaluation,
including any corrective actions with regard to significant deficiencies
and material weaknesses.
Date: May 15, 2003 /s/ James S. Pignatelli
----------------------------------------------
James S. Pignatelli
Chairman, President, and
Chief Executive Officer
52
CERTIFICATION
Pursuant to Section 302 of the Sarbanes-Oxley Act
I, Kevin P. Larson, certify that:
1. I have reviewed this quarterly report on Form 10-Q of Tucson Electric
Power Company;
2. Based on my knowledge, this quarterly report does not contain any untrue
statement of a material fact or omit to state a material fact necessary
to make the statements made, in light of the circumstances under which
such statements were made, not misleading with respect to the period
covered by this quarterly report;
3. Based on my knowledge, the financial statements, and other financial
information included in this quarterly report, fairly present in all
material respects the financial condition, results of operations and
cash flows of the registrant as of, and for, the periods presented in
this quarterly report;
4. The registrant's other certifying officers and I are responsible for
establishing and maintaining disclosure controls and procedures (as
defined in Exchange Act Rules 13a-14 and 15d-14) for the registrant
and we have:
a. designed such disclosure controls and procedures to ensure that
material information relating to the registrant, including its
consolidated subsidiaries, is made known to us by others within
those entities, particularly during the period in which this
quarterly report is being prepared;
b. evaluated the effectiveness of the registrant's disclosure
controls and procedures as of a date within 90 days prior to the
filing date of this quarterly report (the "Evaluation Date"); and
c. presented in this quarterly report our conclusions about the
effectiveness of the disclosure controls and procedures based on
our evaluation as of the Evaluation Date;
5. The registrant's other certifying officers and I have disclosed, based
on our most recent evaluation, to the registrant's auditors and the
audit committee of registrant's board of directors (or persons performing
the equivalent function):
a. all significant deficiencies in the design or operation of internal
controls which could adversely affect the registrant's ability to
record, process, summarize and report financial data and have
identified for the registrant's auditors any material weaknesses in
internal controls; and
b. any fraud, whether or not material, that involves management or
other employees who have a significant role in the registrant's
internal controls; and
6. The registrant's other certifying officers and I have indicated in this
quarterly report whether or not there were significant changes in
internal controls or in other factors that could significantly affect
internal controls subsequent to the date of our most recent evaluation,
including any corrective actions with regard to significant deficiencies
and material weaknesses.
Date: May 15, 2003 /s/ Kevin P. Larson
----------------------------------------------
Kevin P. Larson
Vice President, Chief Financial Officer
and Treasurer
53
EXHIBIT INDEX
12 - Computation of Ratio of Earnings to Fixed Charges - TEP.
15 - Letter regarding unaudited interim financial information.
99 - Statements of Corporate Officers (pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002).
54