UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q
(Mark One)
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For The Quarterly Period Ended September 30, 2001
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF
THE SECURITIES EXCHANGE ACT OF 1934
For the transition period from __________ to __________.
Registrant; State of
Commission Incorporation; Address; IRS Employer
File Number 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 ___
At November 5, 2001, 33,492,150 shares of UniSource Energy Corporation's
Common Stock, no par value (the only class of Common Stock) were outstanding.
UniSource Energy Corporation is the holder of 32,139,434 shares of the
outstanding common stock of Tucson Electric Power Company.
- -------------------------------------------------------------------------------
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................2
Comparative Condensed Consolidated Statements of Cash Flows............3
Comparative Condensed Consolidated Balance Sheets......................4
Condensed Consolidated Statement of Changes in
Stockholders' Equity.................................................5
Tucson Electric Power Company
Comparative Condensed Consolidated Statements of Income................6
Comparative Condensed Consolidated Statements of Cash Flows............7
Comparative Condensed Consolidated Balance Sheets......................8
Condensed Consolidated Statement of Changes in
Stockholders' Equity.................................................9
Notes to Condensed Consolidated Financial Statements
Note 1. Regulatory Accounting..........................................10
Note 2. Accounting for Derivative Instruments and Hedging
Activities...................................................10
Note 3. Millennium Energy Businesses...................................12
Note 4. Business Segments..............................................13
Note 5. Commitments and Contingencies..................................15
Note 6. Wholesale Accounts Receivable and Allowances...................15
Note 7. Income Taxes...................................................17
Note 8. New Accounting Pronouncement...................................18
Note 9. Review by Independent Accountants..............................18
Note 10. Reclassifications..............................................18
Item 2. -- Management's Discussion and Analysis of Financial
Condition and Results of Operations
Overview................................................................19
Factors Affecting Results of Operations
Competition
Retail..............................................................20
Wholesale...........................................................21
Western Energy Markets................................................23
Regulatory Matters....................................................26
Market Risks..........................................................26
Fuel Supply...........................................................28
Future Generating Resources...........................................28
Results of Operations...................................................29
Results of Millennium Energy Businesses.................................33
Results of UED..........................................................34
Dividends on Common Stock...............................................34
Liquidity and Capital Resources
Cash Flows
UniSource Energy....................................................35
TEP.................................................................35
TABLE OF CONTENTS
(concluded)
Investing and Financing Activities
UniSource Energy....................................................36
TEP.................................................................36
Millennium -- Unregulated Energy Businesses.........................36
UED.................................................................38
Safe Harbor for Forward-Looking Statements..............................38
Item 3. -- Quantitative and Qualitative Disclosures About
Market Risk.............................................................39
PART II - OTHER INFORMATION
Item 1. -- Legal Proceedings..............................................40
Item 5. -- Other Information
Additional Financial Data...............................................40
Item 6. -- Exhibits and Reports on Form 8-K...............................40
Signature Page............................................................41
Exhibit Index.............................................................42
DEFINITIONS
The abbreviations and acronyms used in the 2001 Third 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.
AISA....................... Arizona Independent Scheduling Administrator
Association, a temporary organization required
by the ACC Retail Electric Competition Rules.
ALJ........................ FERC Administrative Law Judge.
CDWR....................... California Department of Water Resources.
CISO....................... California Independent System Operator.
Common Stock............... UniSource Energy's common stock, without par
value.
Company or UniSource
Energy................... UniSource Energy Corporation.
Cooling Degree Days........ Calculated by subtracting 75 from the average of
the high and low daily temperatures.
CPX........................ California Power Exchange.
Credit Agreement........... Credit Agreement between TEP and the banks,
dated as of December 30, 1997.
Desert STAR................ The ISO formed in the southwestern United States,
in which TEP is a participant.
ESP........................ Energy Service Provider(s).
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.
FERC....................... Federal Energy Regulatory Commission.
First Mortgage Bonds....... First mortgage bonds issued under the First
Mortgage Indenture, dated as of April 1, 1941,
of Tucson Gas, Electric Light and Power Company
to the Chase National Bank of the City of New
York, as trustee, as supplemented and amended.
GAAP....................... Generally Accepted Accounting Principles.
GES........................ Global Energy Solutions, Inc., a majority-owned
subsidiary of Millennium, which owns 100% of
Global Solar and Infinite Power Solutions.
Global Solar............... Global Solar Energy, Inc., a wholly-owned
subsidiary of GES, which develops and
manufactures thin-film photovoltaic cells.
Infinite Power Solutions... Infinite Power Solutions, Inc., a wholly-owned
subsidiary of GES, which develops thin-film
batteries. .
INICA...................... INICA, Inc., formerly called ITN Energy Systems,
Inc., a Colorado Corporation.
IRS........................ Internal Revenue Service.
ISO........................ Independent System Operator.
ITC........................ Investment tax credit.
ITN........................ ITN Energy Systems, Inc., a company owned 49% by
Millennium and 51% by INICA, which was formed to
provide research, development, and other
services.
kWh........................ Kilowatt-hour(s).
MEH........................ MEH Corporation, a wholly-owned subsidiary of
Millennium, which formerly held a 50% interest
in NewEnergy.
MicroSat................... MicroSat Systems, Inc., a company owned 49% by
Millennium and 51% by INICA, which was formed to
develop and commercialize small-scale satellites.
Millennium................. Millennium Energy Holdings, Inc., a wholly-owned
subsidiary of UniSource Energy.
MW......................... Megawatt(s).
MWh........................ Megawatt-hour(s).
Nations Energy............. Nations Energy Corporation, a wholly-owned
subsidiary of Millennium, and holder of a
minority interest in an independent power project
in Panama.
NewEnergy.................. NewEnergy, Inc., formerly New Energy Ventures,
Inc., a company in which a 50% interest was owned
by MEH.
NOL........................ Net Operating Loss carryback or carryforward for
income tax purposes.
NTUA....................... Navajo Tribal Utility Authority.
DEFINITIONS
(concluded)
PDES....................... Phelps Dodge Energy Services.
PG&E....................... Pacific Gas and Electric Company.
Revolving Credit
Facility................. $100 million revolving credit facility entered
into under the Credit Agreement between a
syndicate of banks and TEP.
RTO........................ Regional Transmission Organization.
Rules...................... The ACC Retail Electric Competition Rules.
SCE........................ Southern California Edison Company.
Settlement Agreement....... TEP's Settlement Agreement approved by the ACC in
November 1999 which provided for electric retail
competition and transition asset recovery.
Springerville.............. Springerville Generating Station.
Springerville Common
Facilities............... Facilities at Springerville used in common with
Springerville Unit 1 and Springerville Unit 2.
Springerville Unit 1....... Unit 1 of the Springerville Generating Station.
Springerville Unit 1 Lease. Leveraged lease arrangement relating to
Springerville Unit 1 and an undivided one-half
interest in certain Springerville Common
Facilities.
TEP........................ Tucson Electric Power Company, the principal
subsidiary of UniSource Energy.
UED........................ UniSource Energy Development Company, a wholly-
owned subsidiary of UniSource Energy, which owns
a 21 MW gas turbine under lease to TEP and
engages in developing generating resources and
other project development services and related
activities.
UniSource Energy........... UniSource Energy Corporation.
WestConnect................ Proposed for-profit RTO formed by the
reorganization of Desert STAR, in which TEP is a
participant.
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 of Tucson Electric Power
Company and its subsidiaries (TEP) as of September 30, 2001,
and the related condensed consolidated statements of income
for each of the three-month and nine-month periods ended
September 30, 2001 and 2000 and the condensed consolidated
statements of stockholders' equity for the nine-month period
ended September 30, 2001, and the condensed consolidated
statements of cash flows for the nine-month periods ended
September 30, 2001 and 2000. These financial statements are
the responsibility of the Company'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 sheets and statements of capitalization
of the Company and of TEP as of December 31, 2000, 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 1, 2001 we expressed an unqualified opinion on
those consolidated financial statements. In our opinion, the
information set forth in the accompanying condensed
consolidated balance sheets as of December 31, 2000, is
fairly stated in all material respects in relation to the
consolidated balance sheets from which it has been derived.
PricewaterhouseCoopers LLP
Los Angeles, California
November 8, 2001
PART I - FINANCIAL INFORMATION
Item 1. FINANCIAL STATEMENTS
- -----------------------------------------------------------------------------
The weather causes seasonal fluctuations in UniSource Energy's sales. As a
result, quarterly results are not indicative of annual operating results. The
quarterly financial statements that follow 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. The year-end condensed balance sheet data was derived from audited
financial statements, but does not include disclosures required by generally
accepted accounting principles. Also see Item 2. - Management's Discussion
and Analysis of Financial Condition and Results of Operations. This
quarterly report should be reviewed in conjunction with UniSource Energy's
2000 Form 10-K.
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME
Three Months Ended
September 30,
2001 2000
(Unaudited)
- ---------------------------------------------------------------------------
-Thousands of Dollars-
Operating Revenues
Electric Retail Sales $212,108 $214,513
Electric Wholesale Sales 216,186 124,706
Net Unrealized Gain (Loss) on Forward Electric
Sales and Purchases (2,916) -
Other 4,284 2,998
- ---------------------------------------------------------------------------
Total Operating Revenues 429,662 342,217
- ---------------------------------------------------------------------------
Operating Expenses
Fuel 67,807 72,392
Purchased Power 211,692 96,873
Coal Contract Amendment Fee - 13,231
Other Operations and Maintenance 42,825 42,794
Depreciation and Amortization 30,401 31,003
Amortization of Transition Recovery Asset 9,627 8,795
Taxes Other Than Income Taxes 12,034 12,363
Income Taxes 7,430 9,473
- ---------------------------------------------------------------------------
Total Operating Expenses 381,816 286,924
- ---------------------------------------------------------------------------
Operating Income 47,846 55,293
- ---------------------------------------------------------------------------
Other Income (Deductions)
Income Taxes (5,346) (1,717)
Interest Income 3,566 2,884
Other Income 9,268 1,291
- ---------------------------------------------------------------------------
Total Other Income (Deductions) 7,488 2,458
- ---------------------------------------------------------------------------
Interest Expense
Long-Term Debt 14,996 16,200
Interest on Capital Leases 22,919 22,901
Other Interest Expense 1,871 1,411
- ---------------------------------------------------------------------------
Total Interest Expense 39,786 40,512
- ---------------------------------------------------------------------------
Income Before Cumulative Effect of Accounting Change 15,548 17,239
Cumulative Effect of Accounting Change - Net of Tax - -
- ---------------------------------------------------------------------------
Net Income $ 15,548 $ 17,239
===========================================================================
Average Shares of Common Stock Outstanding (000) 33,472 32,423
===========================================================================
Basic Earnings per Share
Income Before Cumulative Effect of Accounting Change $0.46 $0.53
Cumulative Effect of Accounting Change - Net of Tax - -
Net Income $0.46 $0.53
===========================================================================
Diluted Earnings per Share
Income Before Cumulative Effect of Accounting Change $0.45 $0.52
Cumulative Effect of Accounting Change - Net of Tax - -
Net Income $0.45 $0.52
===========================================================================
See Notes to Condensed Consolidated Financial Statements.
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME
Nine Months Ended
September 30,
2001 2000
(Unaudited)
- ---------------------------------------------------------------------------
-Thousands of Dollars-
Operating Revenues
Electric Retail Sales $ 518,452 $ 518,694
Electric Wholesale Sales 586,079 230,668
Net Unrealized Gain (Loss) on Forward Electric
Sales and Purchases 4,253 -
Other 11,158 6,809
- ---------------------------------------------------------------------------
Total Operating Revenues 1,119,942 756,171
- ---------------------------------------------------------------------------
Operating Expenses
Fuel 203,900 165,901
Purchased Power 437,673 162,162
Coal Contract Amendment Fee - 13,231
Other Operations and Maintenance 147,450 128,318
Depreciation and Amortization 88,451 86,221
Amortization of Transition Recovery Asset 17,464 14,377
Taxes Other Than Income Taxes 35,870 37,288
Income Taxes 31,451 4,238
- ---------------------------------------------------------------------------
Total Operating Expenses 962,259 611,736
- ---------------------------------------------------------------------------
Operating Income 157,683 144,435
- ---------------------------------------------------------------------------
Other Income (Deductions)
Income Taxes (6,813) (3,445)
Interest Income 11,293 9,370
Other Income 5,408 3,073
- ---------------------------------------------------------------------------
Total Other Income (Deductions) 9,888 8,998
- ---------------------------------------------------------------------------
Interest Expense
Long-Term Debt 46,672 50,229
Interest on Capital Leases 68,307 69,453
Other Interest Expense 4,995 5,611
- ---------------------------------------------------------------------------
Total Interest Expense 119,974 125,293
- ---------------------------------------------------------------------------
Income Before Cumulative Effect of Accounting Change 47,597 28,140
Cumulative Effect of Accounting Change - Net of Tax 470 -
- ---------------------------------------------------------------------------
Net Income $ 48,067 $ 28,140
===========================================================================
Average Shares of Common Stock Outstanding (000) 33,360 32,397
===========================================================================
Basic Earnings per Share
Income Before Cumulative Effect of Accounting Change $1.43 $0.87
Cumulative Effect of Accounting Change - Net of Tax $0.01 -
Net Income $1.44 $0.87
===========================================================================
Diluted Earnings per Share
Income Before Cumulative Effect of Accounting Change $1.39 $0.86
Cumulative Effect of Accounting Change - Net of Tax $0.01 -
Net Income $1.40 $0.86
===========================================================================
See Notes to Condensed Consolidated Financial Statements.
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Nine Months Ended
September 30,
2001 2000
(Unaudited)
- ---------------------------------------------------------------------------
-Thousands of Dollars-
Cash Flows from Operating Activities
Cash Receipts from Electric Retail Sales $542,747 $539,243
Cash Receipts from Electric Wholesale Sales 575,613 200,590
Fuel Costs Paid (213,890) (150,916)
Purchased Power Costs Paid (387,877) (134,001)
Wages Paid, Net of Amounts Capitalized (52,809) (47,426)
Payment of Other Operations and Maintenance Costs (102,544) (76,365)
Capital Lease Interest Paid (78,861) (90,351)
Taxes Paid, Net of Amounts Capitalized (68,104) (63,168)
Interest Paid, Net of Amounts Capitalized (56,506) (61,377)
Income Taxes Paid (30,259) (3)
Interest Received 13,246 12,125
Other 10,888 5,974
- ---------------------------------------------------------------------------
Net Cash Flows - Operating Activities 151,644 134,325
- ---------------------------------------------------------------------------
Cash Flows from Investing Activities
Capital Expenditures (95,202) (78,677)
Investments in and Loans to Millennium
Energy Businesses (19,101) (7,091)
Proceeds from the Sale of Millennium
Energy Businesses 16,631 31,350
Proceeds from the Sale of Real Estate 6,580 -
Purchase of Springerville Lease Debt - (27,633)
Other (2,968) 240
- ---------------------------------------------------------------------------
Net Cash Flows - Investing Activities (94,060) (81,811)
- ---------------------------------------------------------------------------
Cash Flows from Financing Activities
Proceeds from Borrowings under Revolving Credit
Facility - 25,000
Payments on Revolving Credit Facility (47) (25,000)
Payments to Retire Long-Term Debt (1,871) (50,116)
Payments to Retire Capital Lease Obligations (25,894) (38,907)
Common Stock Dividends Paid (10,021) (7,752)
Other 7,791 2,273
- ---------------------------------------------------------------------------
Net Cash Flows - Financing Activities (30,042) (94,502)
- ---------------------------------------------------------------------------
Net Increase (Decrease) in Cash and Cash Equivalents 27,542 (41,988)
Cash and Cash Equivalents, Beginning of Year 163,004 145,288
- ---------------------------------------------------------------------------
Cash and Cash Equivalents, End of Period $190,546 $103,300
===========================================================================
SUPPLEMENTAL CONDENSED CONSOLIDATED CASH FLOW INFORMATION
- ---------------------------------------------------------------------------
Net Income $ 48,067 $ 28,140
Adjustments to Reconcile Net Income to Net Cash Flows
Depreciation and Amortization Expense 88,451 86,221
Coal Contract Amendment Fee - 13,231
Amortization of Transition Recovery Asset 17,464 14,377
Net Unrealized Gains on Forward Electric Sale and
Purchase Contracts (4,723) -
Amortization of Deferred Debt-Related Costs Included
in Interest Expense 1,507 1,257
Deferred Income Taxes 7,961 15,783
Unremitted Losses of Unconsolidated Subsidiaries 10,205 1,549
Gain on Sale of Nations Energy's Holdings (10,737) (2,527)
Market Value Adjustments Related to Nations Energy - 1,499
Other (8,759) 2,316
Changes in Assets and Liabilities which Provided
(Used) Cash Exclusive of Changes Shown Separately
Accounts Receivable (26,024) (47,770)
Materials and Fuel (1,383) 3,583
Accounts Payable 37,971 35,549
Interest Accrued (18,349) (28,077)
Taxes Accrued 11,791 14,875
Other Current Assets (5,213) (10,882)
Other Current Liabilities (4,274) 188
Other Deferred Assets (2,898) 3,688
Other Deferred Liabilities 10,587 1,325
- ---------------------------------------------------------------------------
Net Cash Flows - Operating Activities $151,644 $134,325
===========================================================================
See Notes to Condensed Consolidated Financial Statements.
UNISOURCE ENERGY CORPORATION
COMPARATIVE CONDENSED CONSOLIDATED BALANCE SHEETS
September 30, December 31,
2001 2000
(Unaudited)
- ---------------------------------------------------------------------------
ASSETS - Thousands of Dollars -
Utility Plant
Plant in Service $2,472,401 $2,389,587
Utility Plant Under Capital Leases 741,446 741,446
Construction Work in Progress 77,624 94,789
- ---------------------------------------------------------------------------
Total Utility Plant 3,291,471 3,225,822
Less Accumulated Depreciation and Amortization (1,249,053) (1,186,035)
Less Accumulated Depreciation of Capital Lease
Assets (355,431) (333,497)
- ---------------------------------------------------------------------------
Total Utility Plant - Net 1,686,987 1,706,290
- ---------------------------------------------------------------------------
Investments and Other Property 166,416 121,811
- ---------------------------------------------------------------------------
Current Assets
Cash and Cash Equivalents 190,546 163,004
Accounts Receivable 141,766 115,742
Materials and Fuel 45,782 44,399
Deferred Income Taxes - Current 6,771 17,790
Forward Sale and Purchase Contracts 2,026 -
Other 13,086 19,273
- ---------------------------------------------------------------------------
Total Current Assets 399,977 360,208
- ---------------------------------------------------------------------------
Regulatory and Other Assets
Transition Recovery Asset 335,819 353,283
Income Taxes Recoverable Through Future Revenues 67,048 73,459
Other Regulatory Assets 8,746 7,690
Other Assets 48,978 48,643
- ---------------------------------------------------------------------------
Total Regulatory and Other Assets 460,591 483,075
- ---------------------------------------------------------------------------
Total Assets $2,713,971 $2,671,384
===========================================================================
CAPITALIZATION AND OTHER LIABILITIES
Capitalization
Common Stock Equity $ 412,739 $ 372,169
Capital Lease Obligations 850,135 857,829
Long-Term Debt 1,131,432 1,132,395
- ---------------------------------------------------------------------------
Total Capitalization 2,394,306 2,362,393
- ---------------------------------------------------------------------------
Current Liabilities
Current Obligations Under Capital Leases 18,320 21,147
Current Maturities of Long-Term Debt 1,819 1,725
Accounts Payable 103,862 65,891
Interest Accrued 30,227 63,852
Taxes Accrued 38,602 26,811
Accrued Employee Expenses 12,638 14,405
Other 7,782 8,547
- ---------------------------------------------------------------------------
Total Current Liabilities 213,250 202,378
- ---------------------------------------------------------------------------
Deferred Credits and Other Liabilities
Deferred Income Taxes - Noncurrent 40,678 51,035
Other 65,737 55,578
- ---------------------------------------------------------------------------
Total Deferred Credits and Other Liabilities 106,415 106,613
- ---------------------------------------------------------------------------
Total Capitalization and Other Liabilities $2,713,971 $2,671,384
===========================================================================
See Notes to Condensed Consolidated Financial Statements.
UNISOURCE ENERGY CORPORATION
CONDENSED CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS' EQUITY
Accumulated
Accumulated Other Total
Common Earnings Comprehensive Stockholders'
Stock (Deficit) Income (Loss) Equity
- ----------------------------------------------------------------------------
(Unaudited)
- Thousands of Dollars -
Balances at
December 31, 2000 $ 655,539 $ (283,370) $ - $ 372,169
- ----------------------------------------------------------------------------
Comprehensive Income
(Loss):
2001 Year-to-Date Net
Income - 48,067 - 48,067
Cumulative Effect of
Accounting Change
(net of $9,179,000
income tax benefit) - - (13,827) (13,827)
Reversal of Previously
Recorded Unrealized
Losses (Cumulative Effect)
for Contracts which Settled
During the Period
(net of $5,631,000
income tax expense) - - 8,481 8,481
Unrealized Gain on Cash
Flow Hedges Not Yet
Settled
(net of $2,348,000
income tax expense) - - 3,538 3,538
-----------
Total Comprehensive Income 46,259
-----------
273,770 Shares Issued under
Stock Compensation Plans 4,520 - - 4,520
7,216 Net Shares Purchased
by Deferred Compensation
Trust (216) - - (216)
Dividends Declared - (9,993) - (9,993)
- ----------------------------------------------------------------------------
Balances at
September 30, 2001 $ 659,843 $ (245,296) $ (1,808) $ 412,739
============================================================================
See Notes to Condensed Consolidated Financial Statements.
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME
The weather causes seasonal fluctuations in TEP's sales. As a result,
quarterly results are not indicative of annual operating results. The
quarterly financial statements that follow 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. The year-end condensed balance sheet data was derived from audited
financial statements, but does not include disclosures required by generally
accepted accounting principles. Also see Item 2. - Management's Discussion
and Analysis of Financial Condition and Results of Operations. This
quarterly report should be reviewed in conjunction with TEP's 2000 Form 10-K.
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME
Three Months Ended
September 30,
2001 2000
(Unaudited)
- ---------------------------------------------------------------------------
-Thousands of Dollars-
Operating Revenues
Electric Retail Sales $212,108 $214,513
Electric Wholesale Sales 216,186 124,706
Net Unrealized Gain (Loss) on Forward Electric
Sales and Purchases (2,916) -
Other 2,105 1,282
- ---------------------------------------------------------------------------
Total Operating Revenues 427,483 340,501
- ---------------------------------------------------------------------------
Operating Expenses
Fuel 67,807 72,392
Purchased Power 211,692 96,873
Coal Contract Amendment Fee - 13,231
Other Operations and Maintenance 37,497 37,590
Depreciation and Amortization 29,047 30,826
Amortization of Transition Recovery Asset 9,627 8,795
Taxes Other Than Income Taxes 11,736 12,219
Income Taxes 9,356 11,063
- ---------------------------------------------------------------------------
Total Operating Expenses 376,762 282,989
- ---------------------------------------------------------------------------
Operating Income 50,721 57,512
- ---------------------------------------------------------------------------
Other Income (Deductions)
Income Taxes (2,327) (1,901)
Interest Income 3,107 1,665
Interest Income - Note Receivable from UniSource
Energy 2,351 2,345
Other Income 349 709
- ---------------------------------------------------------------------------
Total Other Income (Deductions) 3,480 2,818
- ---------------------------------------------------------------------------
Interest Expense
Long-Term Debt 14,996 16,200
Interest on Capital Leases 22,907 22,890
Other Interest Expense 1,858 1,405
- ---------------------------------------------------------------------------
Total Interest Expense 39,761 40,495
- ---------------------------------------------------------------------------
Income Before Cumulative Effect of Accounting Change 14,440 19,835
Cumulative Effect of Accounting Change - Net of Tax - -
- ---------------------------------------------------------------------------
Net Income $ 14,440 $ 19,835
===========================================================================
See Notes to Condensed Consolidated Financial Statements.
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF INCOME
Nine Months Ended
September 30,
2001 2000
(Unaudited)
- ---------------------------------------------------------------------------
-Thousands of Dollars-
Operating Revenues
Electric Retail Sales $ 518,452 $ 518,694
Electric Wholesale Sales 586,079 230,668
Net Unrealized Gain (Loss) on Forward Electric
Sales and Purchases 4,253 -
Other 4,526 3,332
- ---------------------------------------------------------------------------
Total Operating Revenues 1,113,310 752,694
- ---------------------------------------------------------------------------
Operating Expenses
Fuel 203,900 165,901
Purchased Power 437,673 162,162
Coal Contract Amendment Fee - 13,231
Other Operations and Maintenance 131,499 116,629
Depreciation and Amortization 85,992 85,875
Amortization of Transition Recovery Asset 17,464 14,377
Taxes Other Than Income Taxes 34,955 36,773
Income Taxes 36,537 7,944
- ---------------------------------------------------------------------------
Total Operating Expenses 948,020 602,892
- ---------------------------------------------------------------------------
Operating Income 165,290 149,802
- ---------------------------------------------------------------------------
Other Income (Deductions)
Income Taxes (7,182) (5,790)
Interest Income 8,956 5,667
Interest Income - Note Receivable from UniSource
Energy 6,978 6,982
Other Income 2,264 1,726
- ---------------------------------------------------------------------------
Total Other Income (Deductions) 11,016 8,585
- ---------------------------------------------------------------------------
Interest Expense
Long-Term Debt 46,672 50,229
Interest on Capital Leases 68,267 69,417
Other Interest Expense 4,982 5,605
- ---------------------------------------------------------------------------
Total Interest Expense 119,921 125,251
- ---------------------------------------------------------------------------
Income Before Cumulative Effect of Accounting Change 56,385 33,136
Cumulative Effect of Accounting Change - Net of Tax 470 -
- ---------------------------------------------------------------------------
Net Income $ 56,855 $ 33,136
===========================================================================
See Notes to Condensed Consolidated Financial Statements.
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
Nine Months Ended
September 30,
2001 2000
(Unaudited)
- ---------------------------------------------------------------------------
-Thousands of Dollars-
Cash Flows from Operating Activities
Cash Receipts from Electric Retail Sales $542,747 $539,243
Cash Receipts from Electric Wholesale Sales 575,613 200,590
Fuel Costs Paid (213,890) (150,916)
Purchased Power Costs Paid (387,877) (134,001)
Wages Paid, Net of Amounts Capitalized (46,079) (41,932)
Payment of Other Operations and Maintenance Costs (80,193) (67,135)
Capital Lease Interest Paid (78,824) (90,315)
Taxes Paid, Net of Amounts Capitalized (65,403) (62,696)
Interest Paid, Net of Amounts Capitalized (56,531) (61,377)
Income Taxes Paid (30,318) (3)
Interest Received 10,736 7,182
Other 690 63
- ---------------------------------------------------------------------------
Net Cash Flows - Operating Activities 170,671 138,703
- ---------------------------------------------------------------------------
Cash Flows from Investing Activities
Capital Expenditures (78,957) (73,679)
Proceeds from the Sale of Real Estate 6,580 -
Other Investments - Net (5,950) (2,411)
- ---------------------------------------------------------------------------
Net Cash Flows - Investing Activities (78,327) (76,090)
- ---------------------------------------------------------------------------
Cash Flows from Financing Activities
Proceeds from Borrowings under Revolving Credit
Facility - 25,000
Payments on Revolving Credit Facility - (25,000)
Payments to Retire Long-Term Debt (1,871) (50,116)
Payments to Retire Capital Lease Obligations (25,802) (38,789)
Other 2,940 1,704
- ---------------------------------------------------------------------------
Net Cash Flows - Financing Activities (24,733) (87,201)
- ---------------------------------------------------------------------------
Net Increase (Decrease) in Cash and Cash Equivalents 67,611 (24,588)
Cash and Cash Equivalents, Beginning of Year 88,712 88,402
- ---------------------------------------------------------------------------
Cash and Cash Equivalents, End of Period $156,323 $ 63,814
===========================================================================
SUPPLEMENTAL CONDENSED CONSOLIDATED CASH FLOW INFORMATION
- ---------------------------------------------------------------------------
Net Income $ 56,855 $ 33,136
Adjustments to Reconcile Net Income to Net Cash Flows
Depreciation and Amortization Expense 85,992 85,875
Coal Contract Amendment Fee - 13,231
Amortization of Transition Recovery Asset 17,464 14,377
Net Unrealized Gains on Forward Electric Sale and
Purchase Contracts (4,723) -
Amortization of Deferred Debt-Related Costs Included
in Interest Expense 1,507 1,257
Deferred Income Taxes 14,805 17,152
Unremitted Losses of Unconsolidated Subsidiaries 1,530 1,540
Interest on Note Receivable from UniSource Energy (6,978) (6,982)
Other 2,568 4,064
Changes in Assets and Liabilities which Provided
(Used) Cash Exclusive of Changes Shown Separately
Accounts Receivable (25,752) (45,526)
Materials and Fuel (757) 3,631
Accounts Payable 35,972 35,084
Interest Accrued (18,349) (28,077)
Taxes Accrued 10,297 14,002
Other Current Assets 665 (4,224)
Other Current Liabilities (2,721) (1,831)
Other Deferred Assets (4,606) 457
Other Deferred Liabilities 6,902 1,537
- ---------------------------------------------------------------------------
Net Cash Flows - Operating Activities $170,671 $138,703
===========================================================================
See Notes to Condensed Consolidated Financial Statements.
TUCSON ELECTRIC POWER COMPANY
COMPARATIVE CONDENSED CONSOLIDATED BALANCE SHEETS
September 30, December 31,
2001 2000
(Unaudited)
- ---------------------------------------------------------------------------
ASSETS - Thousands of Dollars -
Utility Plant
Plant in Service $2,472,401 $2,389,587
Utility Plant Under Capital Leases 741,446 741,446
Construction Work in Progress 77,624 94,789
- ---------------------------------------------------------------------------
Total Utility Plant 3,291,471 3,225,822
Less Accumulated Depreciation and Amortization (1,249,053) (1,186,035)
Less Accumulated Depreciation of Capital Lease
Assets (355,431) (333,497)
- ---------------------------------------------------------------------------
Total Utility Plant - Net 1,686,987 1,706,290
- ---------------------------------------------------------------------------
Investments and Other Property 93,924 92,334
- ---------------------------------------------------------------------------
Note Receivable from UniSource Energy 70,132 70,132
- ---------------------------------------------------------------------------
Current Assets
Cash and Cash Equivalents 156,323 88,712
Interest on Note Receivable from UniSource Energy 6,978 -
Accounts Receivable 148,282 116,580
Materials and Fuel 44,604 43,847
Deferred Income Taxes - Current 209 10,662
Forward Sale and Purchase Contracts 2,026 -
Other 5,920 6,585
- ---------------------------------------------------------------------------
Total Current Assets 364,342 266,386
- ---------------------------------------------------------------------------
Regulatory and Other Assets
Transition Recovery Asset 335,819 353,283
Income Taxes Recoverable Through Future Revenues 67,048 73,459
Other Regulatory Assets 8,746 7,690
Other Assets 33,404 31,361
- ---------------------------------------------------------------------------
Total Regulatory and Other Assets 445,017 465,793
- ---------------------------------------------------------------------------
Total Assets $2,660,402 $2,600,935
===========================================================================
CAPITALIZATION AND OTHER LIABILITIES
Capitalization
Common Stock Equity $ 352,119 $ 295,660
Capital Lease Obligations 849,847 857,519
Long-Term Debt 1,130,524 1,132,395
- ---------------------------------------------------------------------------
Total Capitalization 2,332,490 2,285,574
- ---------------------------------------------------------------------------
Current Liabilities
Current Obligations Under Capital Leases 18,177 21,031
Current Maturities of Long-Term Debt 1,725 1,725
Accounts Payable 109,927 73,955
Interest Accrued 30,227 63,852
Taxes Accrued 35,782 25,485
Accrued Employee Expenses 12,366 14,152
Other 6,691 5,671
- ---------------------------------------------------------------------------
Total Current Liabilities 214,895 205,871
- ---------------------------------------------------------------------------
Deferred Credits and Other Liabilities
Deferred Income Taxes - Noncurrent 51,033 53,980
Other 61,984 55,510
- ---------------------------------------------------------------------------
Total Deferred Credits and Other Liabilities 113,017 109,490
- ---------------------------------------------------------------------------
Total Capitalization and Other Liabilities $2,660,402 $2,600,935
===========================================================================
See Notes to Condensed Consolidated Financial Statements.
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, 2000 $ 651,723 $ (6,357) $(349,706) $ - $ 295,660
- ----------------------------------------------------------------------------
Comprehensive
Income (Loss):
2001 Year-to-Date
Net Income - - 56,855 - 56,855
Cumulative Effect of
Accounting Change
(net of $9,179,000
income tax benefit) - - - (13,827) (13,827)
Reversal of Previously
Recorded Unrealized
Losses (Cumulative
Effect) for Contracts
which Settled During
the Period
(net of $5,631,000
income tax expense) - - - 8,481 8,481
Unrealized Gain on Cash
Flow Hedges Not Yet
Settled (net of
$2,348,000 income
tax expense) - - - 3,538 3,538
-----------
Total Comprehensive Income 55,047
-----------
Other 1,412 - - - 1,412
- ----------------------------------------------------------------------------
Balances at
September 30, 2001 $ 653,135 $ (6,357) $(292,851) $ (1,808) $ 352,119
============================================================================
See Notes to Condensed Consolidated Financial Statements.
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
- ---------------------------------------------------------------------------
NOTE 1. 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 FAS 71, 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 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 cover 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
relating to recovery of TEP's transition costs and standard retail rates,
we discontinued application of FAS 71 to our generation operations.
We continue to apply FAS 71 to the distribution and transmission
portions of TEP's business, our regulated operations. We periodically
assess whether we can continue to apply FAS 71 to these operations. If we
stopped applying FAS 71 to TEP's remaining regulated operations, we would
write off the related balances of TEP's regulatory assets as a charge in
our income statement. Based on the balances of TEP's regulatory assets at
September 30, 2001, if we had stopped applying FAS 71 to TEP's remaining
regulated operations, we would have recorded an extraordinary loss, after-
tax, of approximately $247 million. While regulatory orders and market
conditions may affect our cash flows, our cash flows would not be affected
if we stopped applying FAS 71.
NOTE 2. ACCOUNTING FOR DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES
- ---------------------------------------------------------------------
In 1998, the Financial Accounting Standards Board (FASB) issued
Statement of Financial Accounting Standards No. 133 (FAS 133), "Accounting
for Derivative Instruments and Hedging Activities." A derivative financial
instrument or other contract derives its value from another investment or
designated benchmark. We buy and sell wholesale power using forward
contracts which are considered to be derivatives. Under forward contracts,
TEP commits 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. Forward contracts may consist of sales of TEP's
excess generating capacity, purchases to meet our retail and firm energy
commitments, or trading activity, where forward sales and purchases may be
made within established limits to take advantage of favorable market
opportunities.
There are two types of gains and losses related to forward contracts:
- An unrealized gain or loss is the difference between the contract price
and the market price at any interim date until the contract is settled.
- A realized gain or loss is the difference between the contract price and
the actual cost of the commodity that was purchased or sold. Realized
gains or losses are recorded in the financial statements at the settlement
date.
On January 1, 2001, we adopted FAS 133, and on July 1, 2001, we
applied the guidance in FAS 133 Implementation Issue No. C15 (see below).
The financial statements for 2000 do not reflect the requirements of FAS
133, as we recorded realized gains and losses at the contract settlement
date. FAS 133 requires us to recognize derivative instruments on the
balance sheet as either assets or liabilities measured at fair value and to
record the related unrealized gains and losses throughout the contract
period until settlement. Based on our interpretation of FAS 133 and other
guidance, in the first and second quarters of 2001, we classified our
wholesale forward contracts as follows:
- Normal Purchases and Sales: Our off-peak forward purchases and sales
generally qualify as normal purchases and sales and are excluded from the
requirements of FAS 133. The realized gains and losses on these contracts
are reflected in the income statement at the contract settlement date.
- Cash Flow Hedge: On-peak forward purchase contracts to meet our retail
and firm commitments, as well as on-peak forward sales contracts of our
excess system capacity are generally classified as cash flow hedges. Our
on-peak purchases and sales occur daily from 6 a.m. until 10 p.m., Monday
through Saturday. The unrealized gains and losses related to these forward
contracts are included in Other Comprehensive Income, a component of
stockholders' equity. As the forward contracts are settled and realized
gains or losses are recorded on the income statement, the unrealized gains
and losses are reversed from Other Comprehensive Income.
- Trading Activity: Our trading activity generally consists of forward on-
peak sales and purchases that do not qualify for cash flow hedge treatment.
The unrealized gains and losses related to these forward contracts are
reflected in the income statement. As the forward contracts are settled
and realized gains or losses are recorded, the unrealized gains and losses
are reversed.
On January 1, 2001, we recorded the cumulative effects of adopting FAS
133 in our financial statements by recognizing all derivatives at fair
value and recording the following amounts on our forward contracts as of
January 1, 2001:
Income Statement: after-tax unrealized gain of $470,000.
Balance Sheet:
- Other Comprehensive Income, a component of stockholders' equity:
after-tax unrealized loss of $14 million, and
- Forward Sale and Purchase Contracts Liability of $22 million.
In addition to our forward contracts to buy and sell wholesale power,
we entered into two swap agreements in May 2001 to hedge our risk of
fluctuations in the market price of gas related to approximately a third of
our anticipated gas purchases from June through October 2001. These swaps
are considered derivatives and are designated as cash flow hedges.
Under FAS 133, we record unrealized gains and losses on our forward
contracts and swap agreements and adjust the related asset or liability on
a monthly basis to reflect the market prices at the end of the month. The
market prices used to determine fair value for forward contracts are
estimated based on various factors including broker quotes, exchange
prices, over the counter prices and time value. Beginning in the second
quarter of 2001, we are reporting the unrealized gain (loss) on forward
sales net of the unrealized (gain) loss on forward purchases as a component
of operating revenues. In the first quarter of 2001, we presented the
unrealized gain (loss) on forward sales as a component of operating
revenues and the unrealized (gain) loss on forward purchases as a component
of operating expenses. We have reclassified the first quarter financial
statements to conform to the net presentation, which we believe results in
a more indicative presentation of our actual operating revenues and
expenses.
In June 2001, the FASB approved a conclusion for FAS 133
Implementation Issue No. C15 (Issue C15), "Scope Exceptions: Normal
Purchases and Normal Sales Exception for Option-Type Contracts and Forward
Contracts in Electricity." This guidance provides that power purchase or
sales agreements (i.e. both forward contracts and option contracts),
including capacity contracts, for the purchase or sale of electricity
qualify for the FAS 133 normal purchase and sale exception if certain
criteria are met. We implemented Issue C15 beginning July 1, 2001, on a
prospective basis, and determined that our contracts classified as cash
flow hedges (excluding the gas swaps discussed above) meet the C15 criteria
for the normal purchases and sales exception. As a result, these cash flow
hedge contracts will continue to be reported on the balance sheet at their
fair values as of June 30, 2001 until settlement of the contracts. All
cash flow hedge contracts open at September 30, 2001, including those that
meet the normal purchases and sales exception under C15, will be settled by
December 31, 2001, and as a result, the unrealized losses included in Other
Comprehensive Income as of September 30, 2001 will be reversed from Other
Comprehensive Income by year-end and realized gains or losses will be
recorded on the income statement.
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, we may change the
conclusions that we have reached and, as a result, the accounting treatment
and financial statement impact could change in the future.
NOTE 3. MILLENNIUM ENERGY BUSINESSES
- -------------------------------------
ENERGY TECHNOLOGY INVESTMENTS
At September 30, 2001, Millennium owned 67% of Global Solar Energy,
Inc. (Global Solar) and Infinite Power Solutions, Inc. (Infinite Power
Solutions). INICA, Inc. (formerly ITN Energy Systems, Inc.), a privately
held company, owned the remaining 33%. The financial statements for these
entities are consolidated into the financial statements included in this
document. In 2000, Millennium agreed to provide $26 million in credit to
these entities. As of September 30, 2001, Millennium had funded
approximately $20 million under this credit commitment, $16 million of
which was funded during 2001.
- Global Solar is a developer and manufacturer of flexible thin-film
photovoltaic cells. Global Solar began limited production of photovoltaic
cells in 1999. Target markets for its products include military, space and
commercial applications.
Global Solar has certain federal government contracts that require
Global Solar to contribute to the research and development effort under a
cost share arrangement. Global Solar's share of costs is expensed as
incurred or capitalized in accordance with the terms of the contract.
Global Solar had approximately $0.2 million of remaining cost share
commitment under these contracts at September 30, 2001.
- Infinite Power Solutions is a developer of thin-film batteries and was
established in 2000. INICA contributed certain assets and proprietary and
intellectual property relating to thin-film battery technology.
During 2001, Millennium and INICA formed and began to provide funding
to the following entities, which are accounted for under the equity method
of accounting:
- MicroSat Systems, Inc. (MicroSat) is a space systems company formed for
the purpose of developing and commercializing small-scale satellites.
Millennium owns 49% and the remaining 51% is owned by INICA. Millennium
provided $10 million in equity funding in the nine months ended September
30, 2001, and has agreed to provide an additional $10 million in credit to
the venture. As of September 30, 2001, no draws had been made against this
line of credit. INICA contributed development contracts and proprietary
technologies.
MicroSat has certain federal government contracts that require
MicroSat to contribute to the research and development effort under a cost
share arrangement. MicroSat's share of costs is expensed as incurred or
capitalized in accordance with the terms of the contract. MicroSat's
remaining cost share commitment under these contracts at September 30, 2001
was approximately $8 million.
- ITN Energy Systems, Inc. (ITN) is a product development company that was
formed to provide research and development and other services to Global
Energy Solutions, Inc.'s affiliates, MicroSat and third parties.
Millennium owns 49%, the remaining 51% is owned by INICA. Millennium's
total equity contribution of $3 million was made in the third quarter of
2001. INICA contributed certain contracts, technologies and intellectual
property, including its thermal desalinization technology and its former
name.
Millennium has committed an additional $1 million in credit, of which
$0.5 million has been drawn through September 30, 2001. ITN has certain
federal government contracts that require ITN to contribute to the research
and development effort under a cost share arrangement. ITN's share of costs
is expensed as incurred or capitalized in accordance with the terms of the
contracts. ITN's remaining cost share commitment under these contracts at
September 30, 2001 was approximately $1 million.
Millennium expects to fund approximately $7 million to its various
Energy Technology Investments in the fourth quarter of 2001. A significant
portion of the funding under these agreements will be used for research and
development purposes and other administrative costs. As funds are expended
for these purposes, we recognize expense.
NATIONS ENERGY COMMITMENTS
In September 2001, Nations Energy, a wholly-owned subsidiary of
Millennium, recorded an after-tax gain of $5.6 million from the sale of its
26% equity interest in a power project located in Curacao, Netherland
Antilles. Nations Energy received $5 million in cash proceeds and recorded
an $8 million note receivable from the sale. The note receivable was
recorded at net present value, and 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 addition, in October 2001, Nations Energy's $5
million deposit to fund scheduled equity contributions through April 2003
and its $10 million deposit for possible construction overruns were
returned to Nations Energy.
OTHER MILLENNIUM INVESTMENTS AND COMMITMENTS
In July 2000, Millennium made a $15 million capital commitment to a
limited partnership which will fund energy-related investments. As of
September 30, 2001, Millennium had funded $5.7 million under this
commitment, $4.3 million of which was funded in 2001. The remaining $9.3
million is expected to be invested within two to three years. A member of
the UniSource Energy Board of Directors has a minor investment in the
project. An affiliate of such board member serves as the general partner.
In November 2000, Millennium made a $5 million capital commitment to a
venture capital fund that will focus on information technology, optics and
biotechnology in Tucson, Arizona. A member of the UniSource Energy Board
of Directors owns the company that manages the fund. As of September 30,
2001, Millennium had paid approximately $0.3 million, including funding
under its commitment and organizational and management expenses related to
the fund. Millennium expects to fund approximately $1 million under this
agreement in 2001.
In July 1999, MEH sold its 50% ownership in NewEnergy to the AES
Corporation for approximately $50 million in consideration. As part of the
transaction, two promissory notes were issued by NewEnergy totaling $22.8
million. One of the promissory notes in the principal amount $11.4 million
was paid on July 24, 2000 and the remaining promissory note for $11.4
million was paid on July 23, 2001.
In August 2001, Millennium invested $3 million in Powertrusion
International, Inc. (Powertrusion), a company that manufactures fiberglass
utility poles. The investment provided Millennium a controlling 50.5%
interest in the company. As a result, Millennium consolidated the entity's
balance sheet and results of operations as of the investment date.
Maintaining control of Powertrusion will depend upon many factors,
including providing an additional $2 million in contingent consideration by
August 2002. Contribution of the contingent additional investment is
solely determined by Millennium. Minority shareholder interests in
Powertrusion represent 49.5% of the outstanding common shares and 100% of
the outstanding cumulative preferred shares in the company.
NOTE 4. BUSINESS SEGMENTS
- --------------------------
Based on the way we organize our operations and evaluate performance,
beginning in the third quarter of 2001, we have three reportable business
segments. UniSource Energy's principal business segment is TEP, an
electric utility business. The other reportable business segments consist
of the unregulated energy businesses of Millennium (see Note 3) and UED, a
company that engages in developing generating resources and other project
development services and related activities.
Significant reconciling adjustments consist of the elimination of
intercompany sales between business segments and the elimination of the
intercompany note between UniSource Energy and TEP, as well as the related
interest income and expense. All intercompany activity and balances have
been eliminated. 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
September 30, 2001:
Operating
Revenues
- External $ 427,361 $ 2,301 $ - $ - $ 429,662
- ---------------------------------------------------------------------------
Operating
Revenues
- Intersegment 122 5,741 840 (6,703) -
- ---------------------------------------------------------------------------
Net Income
(Loss) Before
Income Taxes 26,123 3,809 742 (2,350) 28,324
- ---------------------------------------------------------------------------
Net Income
(Loss) 14,440 2,076 446 (1,414) 15,548
- ---------------------------------------------------------------------------
Three months ended
September 30, 2000:
Operating
Revenues
- External $ 340,395 $ 1,822 $ - $ - $ 342,217
- ---------------------------------------------------------------------------
Operating
Revenues
- Intersegment 106 559 - (665) -
- ---------------------------------------------------------------------------
Net Income
(Loss) Before
Income Taxes 32,799 (2,138) - (2,232) 28,429
- ---------------------------------------------------------------------------
Net Income
(Loss) 19,835 (1,254) - (1,342) 17,239
- ---------------------------------------------------------------------------
Nine months ended
September 30, 2001:
Operating
Revenues
- External $1,112,961 $ 6,981 $ - $ - $1,119,942
- ---------------------------------------------------------------------------
Operating
Revenues
- Intersegment 349 9,554 1,120 (11,023) -
- ---------------------------------------------------------------------------
Net Income
(Loss) Before
Income Taxes
and
Cumulative
Effect of
Accounting
Change 100,104 (8,288) 1,019 (6,974) 85,861
- ---------------------------------------------------------------------------
Cumulative
Effect of
Accounting
Change 470 - - - 470
- ---------------------------------------------------------------------------
Net Income
(Loss) 56,855 (5,206) 612 (4,194) 48,067
- ---------------------------------------------------------------------------
Nine months ended
September 30, 2000:
Operating
Revenues
- External $ 752,410 $ 3,761 $ - $ - $ 756,171
- ---------------------------------------------------------------------------
Operating
Revenues
- Intersegment 284 1,283 - (1,567) -
- ---------------------------------------------------------------------------
Net Income
(Loss)
Before Income
Taxes 46,870 (4,765) - (6,282) 35,823
- ---------------------------------------------------------------------------
Net Income
(Loss) 33,136 (1,218) - (3,778) 28,140
- ---------------------------------------------------------------------------
Balance Sheet
- -------------
Total Assets,
September 30,
2001 $2,660,402 $ 141,190 $ 19,647 $(107,268) $2,713,971
Total Assets,
December 31,
2000 $2,600,935 $ 167,331 $ - $ (96,882) $2,671,384
- ---------------------------------------------------------------------------
- ---------------------------------------------------------------------------
NOTE 5. COMMITMENTS AND CONTINGENCIES
- --------------------------------------
TEP COMMITMENTS AND CONTINGENCIES
Four Corners Generating Station Commitment
TEP is a 7% owner of Units 4 and 5 of the Four Corners Generating
Station. The station participation agreement requires that if one of the
participants fails to make its payments for operation of the station when
due, the other station participants must make such payments on behalf of
the defaulting party, in proportion to their ratable ownership interest in
the station, for a period of up to six months. During this time the
defaulting participant is entitled to its share of the power generated by
the station. After the grace period, the defaulting participant must make
its payments in arrears before it would be entitled to its continuing share
of power.
Southern California Edison Company (SCE) is a 48% owner of Units 4 and
5 of the station. SCE has publicly disclosed that due to the high cost of
wholesale power in California which to date it has not been able to recover
from customers, it may no longer be able to continue to meet its financial
obligations. SCE has made all of its payments for the station for periods
through October 31, 2001. However, we are uncertain whether SCE will be
able to continue to make its payments for the remainder of 2001. Based on
the operating budget for the station for the year 2001, in the event that
SCE were to fail to pay, TEP may be required to pay on SCE's behalf, for
the power SCE receives, an average amount of $1 million per month for up to
six months. TEP is unable to predict whether it will be required to make
any such payments on SCE's behalf in the future.
MILLENNIUM COMMITMENTS
See Note 3 for a description of Millennium's commitments.
NOTE 6. WHOLESALE ACCOUNTS RECEIVABLE AND ALLOWANCES
- -----------------------------------------------------
Due to high market prices and various factors influencing supply and
demand, the California energy markets, as administered by the California
Power Exchange (CPX) and the California Independent System Operator (CISO),
became dysfunctional during 2000. These high prices and extraordinary
market conditions affected not only California, but the entire Western
Region of the United States and Canada. During January and February 2001,
SCE and Pacific Gas & Electric Company (PG&E), two of the largest utility
market participants in California, defaulted on payments due to the CPX and
CISO for power consumed in the fourth quarter of 2000 and the first quarter
of 2001. On January 30, 2001, the CPX suspended its day-ahead and day-of
energy trading and subsequently ceased operations and filed for bankruptcy.
PG&E filed for reorganization under Chapter 11 of the U.S. Bankruptcy
Code on April 6, 2001. During the third quarter of 2001, PG&E filed a plan
of reorganization which purports to pay all valid creditor claims in full.
SCE signed a Memorandum of Understanding with the CDWR on April 9, 2001,
which set forth a comprehensive plan calling for legislation, regulatory
action and definitive agreements designed to resolve certain aspects of the
energy crisis and restore SCE's creditworthiness and liquidity. This
Memorandum of Understanding was allowed to expire in mid-August 2001
without regulatory or legislative action being taken. In October 2001, the
California Public Utilities Commission reached a settlement agreement with
SCE, allowing it to recover approximately $3.3 billion of purchased power
costs and avert a potential bankruptcy filing. The settlement agreement
was approved in U.S. District Court on October 5, 2001. On October 30,
2001, a Motions Panel of the U.S. 9th Circuit Court of Appeals remanded to
the U.S. District Court a consumer advocate group's motion for a stay of
the U.S. District Court's judgement approving the settlement agreement.
Although TEP did not make sales directly to either SCE or PG&E in 2000
or 2001, it did sell approximately $58 million of power to the CPX and the
CISO during 2000 and $7 million in January 2001 and therefore is affected
by the defaults and events noted above.
Beginning in January 2001, the California Department of Water
Resources (CDWR) was authorized to make energy purchases on behalf of
California customers. TEP sold $1 million of power to the CDWR in the third
quarter of 2001, and $16 million of power in the first nine months of 2001,
all of which has been paid according to terms. On February 21, 2001, TEP
filed a complaint at the FERC charging that the State of California,
California Governor Gray Davis, and the CPX violated the Federal Power Act
by letting the CDWR seize the forward contracts of SCE and PG&E at the CPX
without prior FERC approval. TEP contends that this seizure violates the
CPX tariff which provides for the liquidation of favorable forward
positions to mitigate a market participant's default amount. This
complaint is pending at the FERC and we are not able to predict the
outcome.
The CPX has withheld some amounts due to parties, including TEP, that
sold power to the CPX in the fourth quarter of 2000 and the first quarter
of 2001. In addition, under default provisions contained in the CPX
tariff, the CPX allocated the defaults of CPX participants to remaining
participants based upon the level of trading activity of each participant
during the preceding three-month period. Not only have initial defaults of
a CPX debtor been charged back to the other participants, but defaults by
other participants on charge-backs have also been charged back. TEP has
not collected the full amount due for sales to the CPX and CISO in the
fourth quarter of 2000 and the first quarter of 2001 and TEP has been
assessed amounts due as charge-backs. A number of CPX participants filed
suit against the CPX in February 2001, and a preliminary injunction was
implemented that precluded the CPX from issuing any more invoices for
charge-backs, attempting to collect on charge-backs or exercising against
collateral. In April 2001, the FERC ordered the CPX to issue new invoices
reflecting the reversal of the charge-backs on the CPX accounting records.
On October 5, 2001, the CPX participant creditors' committee in the
CPX bankruptcy filed a proposed settlement with the FERC that would (i)
return the collateral of each CPX participant, (ii) establish a reserve for
CPX costs and expenses that would be paid for by PG&E and SCE according to
a 67.5% and 32.5% split, respectively, (iii) return CPX chargeback payments
to participants, and (iv) divide the remaining cash and future assets among
the participants based on the net amounts owed to the CPX by both parties.
On October 25, 2001, both PG&E and SCE filed with the FERC their objections
to such settlement on the basis that the proposed settlement was biased and
could subject the two companies to duplicate claims.
We cannot predict the outcome of the PG&E bankruptcy or the
implementation of the SCE settlement agreement, nor the impact that these
issues or the CPX bankruptcy proceedings will have on TEP's ability to
collect the full amounts it is owed by the CPX and CISO.
Also during 2000, the FERC established certain soft caps on prices for
power sold at the CPX. The caps did not have a significant impact on sales
to the CPX during the first three quarters of 2000. However, during the
fourth quarter of 2000 and the first quarter of 2001, prices for power in
the day-ahead and real-time markets frequently exceeded the caps
established by FERC. During March 2001, the FERC issued two orders
requiring certain generators that sold power to California in January and
February 2001 to either refund amounts over specified market prices or
provide further data to defend their transactions. TEP was not named in
either of these orders.
Other parties in California have indicated an intent to seek return of
revenues earned by wholesale power suppliers which they determine to be
"unlawful profits." The determination of what would constitute "unlawful
profits" is unclear at the present time. In June 2001, a FERC
administrative law judge (ALJ) convened a conference to negotiate a
voluntary settlement between California and numerous power generators.
California claims that it was overcharged up to $9 billion for wholesale
power purchases since May 2000. Representatives from over 100 parties and
participants in the western power market, including the state of California
and power generators, negotiated for two weeks but failed to reach an
agreement. In July 2001, based on the ALJ's recommendations, the FERC
ordered hearings to determine refunds/offsets applicable to wholesale sales
into the CISO's spot markets for the period from October 2, 2000 to June
20, 2001. The order established the methodology that will be used to
calculate the amount of refunds. This methodology will likely result in
refunds substantially lower than the $9 billion claimed by California.
On September 25, 2001, a FERC ALJ extended the deadline for issuing
its report on the California refund issue until March 8, 2002. We are not
able to predict the length of and outcome of the FERC hearings and the
outcome of any subsequent lawsuits and appeals that might be filed. As a
participant in the June 2001 refund proceedings, TEP will be subject to any
final refund orders. TEP does not expect its refund liability to exceed
the $16 million already reserved.
We considered the potential non-payment for certain amounts due to TEP
but not yet paid, the charge-back billings to TEP and the potential
implication of the soft caps if they were extended retroactively to the CPX
and CISO markets when we calculated our allowances for doubtful accounts
and potential refunds for wholesale transactions for 2000 and 2001. We
have recorded allowances amounting to approximately $16 million, $7 million
of which was recorded in the first quarter of 2001 and $9 million of which
was recorded in the fourth quarter of 2000. These allowances reserve in
full the unpaid amounts which are past due to TEP. We recorded no such
allowances in periods prior to the fourth quarter of 2000 or subsequent to
the first quarter of 2001.
While some actions have occurred since the first quarter that appear
to indicate positive intent for parties to repay TEP at least a portion of
the amounts remaining uncollected, we believe there is insufficient
information at present to predict any specific amount which TEP might
receive, or to reverse any portion of the reserves recorded. More
information could become available in the future that would lead us to
conclude that repayment of some portion or all of the uncollected amounts
is probable. If this were to occur, we would decrease the amount of the
reserve accordingly. We are unable to predict whether any such actions
will occur.
Accounts receivable from Electric Wholesale Sales, net of allowances,
totaled $71 million at September 30, 2001 and $64 million at December 31,
2000. These amounts are included in Accounts Receivable on the balance
sheet. These balances, net of the above-mentioned allowances, have been
collected in full as of the date of this filing.
NOTE 7. INCOME TAXES
- ---------------------
The differences between the income tax expense and the amount obtained
by multiplying pre-tax income by the U.S. statutory federal income tax rate
of 35% are as follows:
UniSource Energy
----------------------------------------
Three Months Ended Nine Months Ended
September 30, September 30,
2001 2000 2001 2000
- --------------------------------------------------------------------------
- Thousands of Dollars -
Federal Income Tax Expense at
Statutory Rate $ 9,913 $ 9,950 $ 30,325 $ 12,538
State Income Tax Expense,
Net of Federal Deduction 1,387 1,393 4,245 1,756
Depreciation Differences
(Flow Through Basis) 1,250 1,066 3,856 3,201
Foreign Operations of
Millennium Energy
Businesses 11 18 12 (1,655)
Reduction in Valuation
Allowance - Benefit - (1,200) - (8,200)
Other 215 (37) 138 43
- --------------------------------------------------------------------------
Total Federal and State Income
Tax Expense $ 12,776 $ 11,190 $ 38,576 $ 7,683
==========================================================================
TEP
---------------------------------------
Three Months Ended Nine Months Ended
September 30, September 30,
2001 2000 2001 2000
- --------------------------------------------------------------------------
- Thousands of Dollars -
Federal Income Tax Expense at
Statutory Rate $ 9,143 $ 11,480 $ 35,310 $ 16,405
State Income Tax Expense,
Net of Federal Deduction 1,280 1,607 4,943 2,296
Depreciation Differences
(Flow Through Basis) 1,250 1,066 3,856 3,201
Reduction in Valuation
Allowance - Benefit - (1,200) - (8,200)
Other 10 11 (78) 32
- --------------------------------------------------------------------------
Total Federal and State Income
Tax Expense $ 11,683 $ 12,964 $ 44,031 $ 13,734
==========================================================================
Income tax expense included in the income statements consists of the
following:
UniSource Energy
------------------------------------------
Three Months Ended Nine Months Ended
September 30, September 30,
2001 2000 2001 2000
- --------------------------------------------------------------------------
- Thousands of Dollars -
Operating Expenses $ 7,430 $ 9,473 $ 31,451 $ 4,238
Other Income (Deductions) 5,346 1,717 6,813 3,445
Cumulative Effect of
Accounting Change - - 312 -
- --------------------------------------------------------------------------
Total Income Tax Expense $ 12,776 $ 11,190 $ 38,576 $ 7,683
==========================================================================
TEP
----------------------------------------
Three Months Ended Nine Months Ended
September 30, September 30,
2001 2000 2001 2000
- --------------------------------------------------------------------------
- Thousands of Dollars -
Operating Expenses $ 9,356 $ 11,063 $ 36,537 $ 7,944
Other Income (Deductions) 2,327 1,901 7,182 5,790
Cumulative Effect of
Accounting Change - - 312 -
- --------------------------------------------------------------------------
Total Income Tax Expense $ 11,683 $ 12,964 $ 44,031 $ 13,734
==========================================================================
Due to the financial restructuring, a change in TEP's ownership
occurred for tax purposes in December 1991. This change limits our use of
the NOL and ITC generated before 1992 under the tax code. At December 31,
2000, we had approximately $138 million of NOL and $20 million of ITC
subject to the pre-1992 limitation and $164 million of NOL not subject to
the limitation. Because of the valuation allowance amounts recorded, we do
not expect these annual limitations to have a material adverse impact on
the financial statements.
NOTE 8. NEW ACCOUNTING PRONOUNCEMENT
- ------------------------------------
In June 2001, the FASB issued Statement of Financial Accounting
Standards No.143 (FAS 143), "Accounting for Asset Retirement Obligations."
FAS 143 addresses financial accounting and reporting for obligations
associated with the retirement of tangible long-lived assets and the
associated retirement costs. We are required to comply with FAS 143
beginning January 1, 2003. We are evaluating the impact of FAS 143 on our
financial statements.
NOTE 9. REVIEW BY INDEPENDENT ACCOUNTANTS
- ------------------------------------------
With respect to the unaudited condensed consolidated financial
information of UniSource Energy and TEP for the three-month and nine-month
periods ended September 30, 2001 and 2000, 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 November 8, 2001 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.
NOTE 10. RECLASSIFICATIONS
- ---------------------------
We have made reclassifications to the first quarter of 2001 (see Note 2)
and the prior year financial statements for comparative purposes. These
reclassifications had no effect on net income.
ITEM 2. - MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND
RESULTS OF OPERATIONS
- -------------------------------------------------------------------------------
UniSource Energy Corporation (UniSource Energy) is a holding company
that owns the outstanding common stock of Tucson Electric Power Company
(TEP), Millennium Energy Holdings, Inc. (Millennium), and UniSource Energy
Development Company (UED). TEP is an electric utility which has provided
electric service to the community of Tucson, Arizona, for over 100 years
and whose revenues reached $1 billion, for the first time, in 2000.
Millennium is a holding company that invests in unregulated ventures
related to the energy business. UED was established in February 2001 and
engages in developing generating resources and other project development
services and related activities, including the proposed expansion of the
Springerville Generating Station through construction of Springerville
Units 3 and 4. We conduct our business in these three primary business
segments--TEP's Electric Utility Segment, the Millennium Energy Businesses
Segment, and the UniSource Energy Development Segment.
Management's Discussion and Analysis explains the general financial
condition and the results of operations for UniSource Energy and its three
primary business segments and includes the following:
* operating results during the third quarter and first nine months of
2001 compared with the same periods in 2000,
* changes in liquidity and capital resources during the third quarter
and first nine months of 2001, and
* expectations of identifiable material trends which may affect our
business in the future.
TEP is the principal operating subsidiary of UniSource Energy and
accounts for substantially all of its assets and revenues. 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 seasonal nature of the electric
utility business causes operating results to vary significantly from
quarter to quarter. At September 30, 2001, Millennium's unregulated energy-
related affiliates comprised approximately 5% of total assets, but at times
have had a significant impact on our consolidated net income and cash
flows. At September 30, 2001, UED's unregulated business segment comprised
less than 1% of total assets, but may have a significant impact on our
consolidated net income and cash flows in the future.
Management's Discussion and Analysis should be read in conjunction
with UniSource Energy's and TEP's 2000 Form 10-K and with the Condensed
Consolidated Financial Statements, beginning on page 2, which present the
results of operations for the quarters and nine month periods ended
September 30, 2001 and 2000. Management's Discussion and Analysis explains
the differences between periods for specific line items of the Condensed
Consolidated Financial Statements.
OVERVIEW
- --------
UniSource Energy recorded net income of $15.5 million for the third
quarter of 2001, and net income of $48.1 million for the first nine months
of 2001. This compares with net income of $17.2 million in the third
quarter of 2000 and net income of $28.1 million for the first nine months
of 2000.
In the third quarter of 2001, TEP contributed net income of $14.4
million, compared with $19.8 million in the third quarter of 2000. The
reduced earnings resulted from: (1) reduced retail sales and revenues due
to relatively mild summer weather and reduced consumption by mining
customers and (2) higher purchased power expenses related to forward gas
and electricity hedge purchases to assure service reliability during the
summer months. Lower earnings at TEP were somewhat offset by a $2.1
million net gain at Millennium resulting from a $5.6 million net gain from
the sale of the largest independent power project owned by its subsidiary,
Nations Energy.
For the nine months ended September 30, 2001, TEP contributed $56.9
million, compared with $33.1 million in the same period of 2000. This
improvement for the nine month period is due to the strong performance by
TEP's wholesale marketing activities during the first five months of 2001,
when wholesale energy prices in the western U.S. were significantly higher
than in the third quarter of 2001. See Results of Operations for further
detail.
Outlook and Strategy
--------------------
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:
* Continue to maintain our transmission and distribution system to
reliably serve our retail customers.
* Efficiently manage our generating resources and add capacity as
necessary to serve our retail customers. We added peaking resources
in the Tucson area to support expected growth in 2001.
* Evaluate the expansion of the Springerville Generating Station through
construction of Springerville Units 3 and 4. This additional generating
capacity would provide energy under long-term contracts to potential
wholesale power purchasers in Arizona and New Mexico and allow us to
spread the fixed costs of the existing Springerville Common Facilities
over two additional generating units.
* Take advantage of opportunities to sell in the wholesale power markets
while carefully managing the risks associated with such activities.
* Look for ways to reduce or control operating costs in order to improve
profitability. Because our Settlement Agreement provides for a retail
rate cap through 2008, we can benefit from cost savings and from
expected growth in our retail customer base.
* Continue to use some of our cash flows to reduce TEP's leverage. In
the previous three years, we prepaid approximately $34 million in First
Mortgage Bonds and invested $54 million in Springerville Unit 1 lease
debt, in addition to our required debt retirements of $51 million. We
will continue to look for opportunities to retire or refinance higher
coupon debt and make additional investments in lease obligations.
* Make ongoing investments in our technology affiliates. Although we
will record certain research and development expenses and experience
some losses in these investments, we believe that over time these
ventures will become profitable.
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.
FACTORS AFFECTING RESULTS OF OPERATIONS
- ---------------------------------------
COMPETITION
-----------
RETAIL
The electric utility industry is undergoing significant regulatory
change designed to encourage competition in the sale of electricity and
related services. As of January 1, 2001, all of TEP's retail customers are
eligible to choose an alternate energy supplier. Currently, none of TEP's
customers are being served by energy service providers (ESPs) although
there is one certified ESP in TEP's retail service area. It is possible,
however, that with open access in our retail service territory, customers
may elect to purchase their energy requirements from ESPs in the future.
TEP also competes against gas service suppliers and others who provide
energy services.
TEP will continue to serve certain large retail customers under
negotiated contracts. TEP has contracts with two major mining customers.
One of these contracts extends to 2006, with pricing tied, within a range,
to the price of copper. This customer curtailed production at its
facilities in TEP's service area during the second and third quarters of
2001. TEP used this capacity to service its retail load during this peak
energy demand period and to sell into the wholesale market. TEP also had a
load management agreement with this customer for the summer peak demand
period. TEP's other major mining customer curtailed production at its
facilities in TEP's service area during August and September 2001 because
of economic conditions affecting its industry. In October 2001, this
customer announced layoffs and further curtailments in production due to
the continuing deterioration in market conditions.
TEP's Settlement Agreement and Retail Electric Competition Rules
----------------------------------------------------------------
In December 1996, the ACC adopted the Retail Electric Competition
Rules (Rules) that provided a framework for the introduction of retail
electric competition in Arizona. These Rules, as amended and modified,
were approved by the ACC in September 1999. For TEP, the Rules became
effective in January 2000, and consumer choice was available to all
customers by January 1, 2001. TEP has met all conditions required by the
ACC to facilitate electric retail competition, including ACC approval of
TEP's direct access tariffs. However, 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.
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. The Settlement Agreement provides,
among other things, that TEP cap its retail rates until December 31, 2008,
except under certain circumstances. These include the impact of (a)
termination of the Fixed Competitive Transition Charge component of retail
rates as a result of the early collection of $450 million of transition
recovery assets; (b) changes in transmission charges due to regional
transmission organizations; and (c) a transmission and distribution rate
filing required in June 2004 which may result in lower rates. The
Settlement Agreement also requires TEP to transfer its generating and other
competitive assets to a subsidiary by December 31, 2002.
The status of the Rules and the ability of ESPs to continue to sell
competitive services may be subject to change due to recent court
proceedings. Several parties, including certain rural electric
cooperatives (Cooperatives), filed lawsuits in Maricopa County Superior
Court challenging the Rules, contending, among other things, that allowing
marketplace competition to determine rates violated the ACC's
constitutional duty to set rates. In November 2000, the Court found the
Rules to be unconstitutional and unlawful due to the failure of the Rules
to establish a fair value rate base for competitive ESPs and because
certain of the Rules were not submitted for certification to the Arizona
Attorney General. The Court also invalidated all ACC orders granting
certificates of convenience and necessity to competitive ESPs in Arizona.
The ACC, RUCO (Residential Utility Consumer Office) and certain large
industrial customers appealed the decision to the Court of Appeals. In
addition, the Cooperatives filed a notice of cross appeal of certain
aspects of the decision. Implementation of the judgement was stayed and the
Rules remain in effect pending the outcome of the appeals.
TEP cannot predict the effect of the recent court decision or the
outcome of the appeals to which it is a party or the effect of the
judgement, if affirmed upon appeal, on the introduction of retail electric
competition in Arizona.
WHOLESALE
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. 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 United States;
* availability of capacity throughout the western United States;
* restructuring of the electric utility industry in Arizona, California
and other western states;
* the FERC-ordered price mitigation plan which began June 20, 2001;
* the availability and price of natural gas;
* precipitation, which affects hydropower availability;
* transmission constraints; and
* environmental restrictions and the cost of compliance.
The average market price for around-the-clock energy based on the Dow
Jones Palo Verde Index increased significantly in 2000 compared with 1999
and in the nine months ended September 30, 2001 compared with the same
period in 2000, as shown below.
Average Market Price for Around-the-Clock Energy MWh
----------------------------------------------------------------
Year ended December 31, 2000 $ 87
Year ended December 31, 1999 26
Quarter ended September 30, 2001 40
Quarter ended September 30, 2000 124
Nine months ended September 30, 2001 117
Nine months ended September 30, 2000 72
In June 2001 market prices for electricity began to fall significantly
and continued to fall in the third quarter 2001. This reduction was due to
a number of factors, including more generation online in the western U.S.,
lower natural gas prices, and the implementation of the FERC-ordered price
mitigation plan beginning June 20, 2001. See Western Energy Markets,
below. As of November 2001, the average forward around-the-clock market
price for the balance of 2001 and 2002 will be approximately $30 per MWh,
based on the Dow Jones Palo Verde Index.
We cannot predict whether these lower prices will continue, or whether
changes in various factors that influence demand and capacity will cause
prices to rise again during the remainder of 2001 and 2002.
New Long-Term Wholesale Power Contract
--------------------------------------
In the first quarter of 2001, TEP signed a five-year wholesale
contract to supply 60 MW of electricity to Phelps Dodge Energy Services
(PDES). The contract calls for TEP, beginning in March 2001, to supply the
power at all times except during TEP's peak customer energy demand period,
from July through September of each year. It also gives PDES the option of
receiving the power at several of its operations outside TEP's service
territory in Arizona and New Mexico. Under the contract, TEP can interrupt
delivery of power if the utility experiences significant loss of any
electric generating resources. TEP expects the contract to generate
revenues of about $30 million annually through 2006.
Transmission Access
-------------------
In 1997, TEP and other transmission owners and users located in the
southwestern U.S. began to investigate the feasibility of forming an
Independent System Operator (ISO) for the region. As a result, they formed
a non-profit corporation named Desert STAR in September 1999. In December
1999, the FERC issued FERC Order 2000, which established timelines for all
transmission owning entities to join a Regional Transmission Organization
(RTO) and defined the minimum characteristics and functions of an RTO.
In June 2001, Desert STAR and seven southwestern electric utilities,
including TEP, submitted an informational filing with the FERC outlining
their proposal for an RTO encompassing about 380,000 square miles in
Arizona, New Mexico, Colorado, eastern Wyoming, western Texas, southern
Nevada and southern California. In this filing, the utilities indicated to
the FERC that they were considering a change in the proposed governance
structure of Desert STAR.
In July 2001, the FERC ordered existing independent system operators
to consolidate into four regional transmission operators: Northeast,
Southeast, Midwest and West. In September 2001, the FERC recommended the
development of a single RTO for the Western Region, consolidating Desert
STAR and the entity "RTO West", but excluding California. The FERC also
stated that transmission-owning utilities should join an RTO by December
15, 2001. The FERC has since softened its stance with respect to the
formation of four regional transmission operators and the December 15th
deadline, but remains committed to standardizing rules for interconnection
and the creation of a seamless nationwide market.
TEP and five other southwestern utilities filed agreements and
operating protocols with the FERC in October 2001 to form a new, for-profit
RTO to be known as WestConnect to replace Desert STAR. WestConnect is
based primarily on policies and procedures developed in the Desert STAR
stakeholder process. It will be responsible for security, reservations,
scheduling, transmission expansion and planning, and congestion management
for the regional transmission system. It will also focus on ensuring
reliability, nondiscriminatory open-access, and independent governance.
WestConnect is working with members of other regional RTOs in the West and
Pacific Northwest in an attempt to expand its service territory to form a
single western RTO, as envisioned by the FERC. WestConnect is projected to
begin operations in early 2004. The reorganization of Desert STAR into
WestConnect will be subject to approval by the FERC and certain state
regulatory authorities in the region.
The ACC Retail Electric Competition Rules also required the formation
and implementation of an Arizona Independent Scheduling Administrator
Association (AISA). The purpose of the AISA is to oversee the application
of operating protocols to ensure statewide consistency for transmission
access. The AISA is anticipated to be a temporary organization until the
implementation of an ISO or RTO. TEP participated in the creation of the
AISA, a not-for-profit entity, and the compliance filing at the FERC for
approval of its rates and protocols for operation. In June 2001, the FERC
accepted the compliance filing and conditionally accepted service
agreements filed by the AISA under its tariff, effective May 3, 2001.
However, the FERC denied a request for rehearing of its conclusion that
retail customers choosing to remain with the incumbent supplier under
bundled retail Standard Offer rates approved by the ACC will be taking
unbundled retail transmission service under the jurisdiction of the FERC.
The ACC appealed this decision, and the AISA intervened on behalf of the
ACC. The case is pending before the 9th Circuit Court of Appeals. In July
2001, TEP began assessing customers a fee to help fund the AISA. TEP
continues to participate with the other affected utilities in developing
the AISA's structure and protocols in response to retail competition.
On July 24, 2001, the ACC Commissioners initiated a 90-day comment
period to provide stakeholders the opportunity to comment on a list of
issues related to the AISA. Among the issues to be discussed, is a
proposal by one of the Commissioners to end the obligation of Arizona
utilities to fund and participate in the AISA because the AISA has
fulfilled its obligation to develop transmission operating protocols. A
report from the ACC staff to the ACC was due at the end of October, but the
deadline for submitting the report was extended. The ACC may then hold an
open meeting to discuss the results of the report.
WESTERN ENERGY MARKETS
----------------------
Due to high market prices and various factors influencing supply and
demand, the California energy markets, as administered by the CPX and the
CISO, became dysfunctional during 2000. These high prices and
extraordinary market conditions affected not only California, but the
entire Western Region of the United States and Canada. During January and
February 2001, SCE and PG&E, two of the California utilities that are the
largest market participants, defaulted on payments due to the CPX and CISO
for power consumed in the fourth quarter of 2000 and the first quarter of
2001. On January 30, 2001, the CPX suspended its day-ahead and day-of
energy trading and subsequently ceased operations and filed for bankruptcy.
Beginning in January 2001, the California Department of Water Resources
(CDWR) was authorized to make energy purchases on behalf of California
customers. PG&E filed for reorganization under Chapter 11 of the U.S.
Bankruptcy Code on April 6, 2001. SCE signed a Memorandum of Understanding
(MOU) with the CDWR on April 9, 2001, which set forth a comprehensive plan
calling for legislation, regulatory action and definitive agreements
designed to resolve certain aspects of the energy crisis and restore SCE's
creditworthiness and liquidity.
During the third quarter of 2001, PG&E filed a plan of reorganization
which purports to pay all valid creditor claims in full. The SCE MOU was
allowed to expire in mid-August 2001 without regulatory or legislative
action being taken. In October 2001, the California Public Utilities
Commission reached a settlement agreement with SCE, allowing it to recover
approximately $3.3 billion of purchased power costs and avert a potential
bankruptcy filing. The settlement agreement was approved in U.S. District
Court on October 5, 2001. On October 30, 2001, a Motions Panel of the U.S.
9th Circuit Court of Appeals remanded to the U.S. District Court a consumer
advocate group's motion for a stay of the U.S. District Court's judgement
approving the settlement agreement.
Although TEP did not make sales directly to either of these utilities
in 2000 or 2001, it did make sales to the CPX and CISO and therefore is
affected by the defaults and events noted above. We cannot predict the
outcome of the PG&E bankruptcy or the implementation of the SCE settlement
agreement, and the effect on TEP's ability to collect the full amounts it
is owed by the CPX and CISO.
Payment Defaults and Allowances for Doubtful Accounts
-----------------------------------------------------
TEP sold approximately $58 million of power to the CPX and CISO during
2000 and $7 million during January of 2001. As a result of payment
defaults by market participants, TEP's collection shortfall was
approximately $9 million for sales made in 2000 and $7 million for sales
made in 2001. We recorded an allowance for doubtful accounts and potential
refunds for wholesale transactions for the full amount of these uncollected
amounts in the fourth quarter of 2000 and the first quarter of 2001.
Reserves for potential non-payment of amounts due to TEP for sales to the
CPX and CISO during 2000 and 2001 total $16 million. TEP sold $1 million
of power to the CDWR in the third quarter of 2001, and a total of $16
million of power for the first nine months of 2001, all of which has been
paid according to terms.
Under default provisions contained in the CPX tariff, the CPX
allocated the defaults of CPX participants to remaining participants based
upon the level of trading activity of each participant during the preceding
three-month period. Not only were initial defaults of a CPX debtor charged
back to the other participants, but defaults by other participants on
charge-backs were also charged back. A number of CPX participants filed
suit against the CPX in February 2001, and a preliminary injunction was
implemented that precluded the CPX from issuing any more invoices for
charge-backs, attempting to collect on charge-backs or exercising against
collateral. In April 2001, the FERC ordered the CPX to issue new invoices
reflecting the reversal of the charge-backs on the CPX accounting records.
As noted above, the CPX has ceased operations and filed for bankruptcy.
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
bankruptcy stay.
On October 5, 2001, the CPX participant creditors' committee in the
CPX bankruptcy filed a proposed settlement with the FERC that would (i)
return the collateral of each CPX participant, (ii) establish a reserve for
CPX costs and expenses that would be paid for by PG&E and SCE according to
a 67.5% and 32.5% split, respectively, (iii) return CPX chargeback payments
to participants, and (iv) divide the remaining cash and future assets among
the participants based on the net amounts owed to the CPX by both parties.
On October 25, 2001, both PG&E and SCE filed with the FERC their objections
to such settlement on the basis that the proposed settlement was biased and
could subject the two companies to duplicate claims.
While some actions have occurred since the first quarter that appear
to indicate positive intent for parties to repay TEP at least a portion or
all of the amounts remaining uncollected, we believe there is insufficient
information at present to predict any specific amount which TEP might
receive, or to reverse any portion of the reserves recorded. More information
could become available in the future that would lead us to conclude that
repayment of some portion of the uncollected amounts is probable. If this
were to occur, we would decrease the amount of the reserve accordingly.
We are unable to predict whether any such actions will occur.
Department of Energy Orders
---------------------------
On December 14, 2000, the Secretary of Energy issued an order designed
to address the electric emergency in California. The order required
entities, including TEP, "to sell electricity to the California ISO that is
available in excess of electricity needed by each entity to render service
to its firm customers." This order was extended several times due to the
continuation of the emergency situation. The order was allowed to expire
on February 7, 2001. Another emergency order requiring four generators
(not including TEP) to continue to sell power was extended through March
16, 2001.
During early January 2001, TEP sold approximately $7 million of energy
to the CPX and the CISO. After January 12, however, planned generator
maintenance and increased firm customer demand resulted in a decrease of
excess energy available for sale from TEP to California. Furthermore, the
most critical energy shortages were in Northern California. Due to
transmission constraints, energy could not be moved from the South, where
our generation is located, to the North. Therefore, requests for power
under the Department of Energy orders were minimal after January 12, 2001.
FERC Matters
------------
On February 21, 2001, TEP filed a complaint at the FERC charging that
the state of California, California Governor Gray Davis, and the CPX
violated the Federal Power Act by letting the CDWR seize the forward
contracts of SCE and PG&E at the CPX without prior FERC approval. TEP
contends that this seizure violates the CPX tariff which provides for the
liquidation of favorable forward positions to mitigate a market
participant's default amount. TEP's complaint requests the FERC to: void
the seizure of these assets by Governor Davis; require the State of
California to pay fair market value for the contracts or assume the
wholesale power liabilities of PG&E and SCE to the CPX; and declare that
the wholesale rates produced under the CPX tariffs are just and reasonable
and should be collected from the utilities' retail customers. This
complaint is pending at the FERC. In September 2001, however, the 9th
Circuit Court ruled in a similar case filed by Duke Energy Trading and
Marketing, LLC (Duke) that Governor Davis illegally took control of long-
term energy contracts held by California's utilities. The Court remanded
the case to the district court with instructions that a judgement be
entered in favor of Duke and that an injunction be entered against Governor
Davis. We are not able to predict the outcome of our lawsuit at the FERC.
During March 2001, the FERC issued two orders requiring certain
generators that sold power to California in January and February 2001 to
either refund amounts over specified market prices or provide further data
to defend their transactions. TEP was not named in either of these orders.
On June 19, 2001, the FERC issued an order adopting a price mitigation
plan applicable to certain wholesale power sales in California and
throughout the western United States during the period June 20, 2001
through September 30, 2002. This order applies to spot market (day-ahead
and hour-ahead) transactions in the western United States when operating
reserves fall below 7.5% in California and the CISO calls a Stage 1 alert.
The market price is then capped at the operating cost of the highest cost
unit in operation during the Stage 1 alert. The price during non-Stage 1
alert periods is based on 85% of the price established during the most
recent Stage 1 alert. Sellers that do not wish to establish rates on the
basis of this price mitigation plan may propose cost-of-service rates
covering all of their generating units in the Western Systems Coordinating
Council for the duration of the mitigation plan. Since the adoption of
this plan, wholesale market prices in the West have continued to drop.
On June 25, 2001, a FERC administrative law judge (ALJ) convened a
conference to negotiate a voluntary settlement between California and
numerous power generators. California claims that it was overcharged up to
$9 billion for wholesale power purchases since May 2000. Representatives
from over 100 parties and participants in the western power market,
including the state of California and power generators, negotiated for two
weeks but failed to reach an agreement.
In July 2001, based on the ALJ's recommendations, the FERC ordered
hearings to determine refunds/offsets applicable to wholesale sales into
the California ISO's spot markets for the period from October 2, 2000 to
June 20, 2001. The order established the methodology that will be used to
calculate the amount of refunds. The FERC methodology specified that the
price-mitigation formula contained in its June 19, 2001 order be applied to
the period from October 2, 2000 to June 20, 2001. This methodology will
likely result in refunds substantially lower than the $9 billion claimed by
California.
On September 25, 2001, the ALJ extended the deadline for issuing its
report on the California refund issue until March 8, 2002. We are not able
to predict the length of and outcome of the FERC hearings and the outcome
of any subsequent lawsuits and appeals that might be filed. As a
participant in the June 2001 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 Western Energy
Markets, Payment Defaults and Allowances for Doubtful Accounts above.
There are several other outstanding legal issues, complaints, and
lawsuits concerning the California energy crisis related to the FERC,
wholesale power suppliers, SCE, PG&E, the CPX and CISO. New events and
issues related to the California energy crisis arise each day, and we
cannot predict the outcome of these issues or lawsuits. We believe,
however, that we are adequately reserved for our transactions with the CPX
and CISO. See Note 6 of Notes to Financial Statements.
SCE Power Exchange Agreement
----------------------------
As part of a 1992 litigation settlement, TEP and SCE agreed to a ten-
year power exchange agreement. The agreement began in May 1995 and
requires SCE to provide firm system capacity of 110 MW to TEP during summer
months. TEP is obligated to return to SCE in the winter months the same
amount of energy that it received during the preceding summer. For
example, in the summer of 2000, TEP received approximately 140,000 MWh from
SCE and returned the same amount during the winter months from November
2000 to February 2001. Since 1995, TEP has relied upon the 110 MW provided
under this agreement as a firm source of energy to supply its retail load
during the peak summer months. During the summer of 2000, there were two
days when power emergencies were called in California and SCE did not
deliver energy to TEP. This caused TEP to have to purchase power for
several peak hours of the day at high spot power prices. TEP believes the
agreement requires SCE to purchase power for TEP's benefit under those
circumstances, and during subsequent power alerts, SCE did purchase and
provide power to TEP under the agreement. During the summer of 2001 (May
15 to September 15), SCE delivered energy to TEP as required by the terms
of this agreement, except for limited occasions in the second quarter of
2001.
As TEP entered the summer peaking season of 2001, there was considerable
uncertainty as to the ongoing availability of the 110 MW resource because
of the continuing energy crisis in California and the deteriorating
financial condition of SCE. To mitigate the risk of loss of this resource,
TEP relied upon its two new peaking resources that went in-service in June
2001, interruptible contracts, load shifting by large mining customers, and
reserve sharing with other utilities. To ensure service reliability, TEP
purchased power under forward contracts at the beginning of summer at
prices in excess of the cost of the SCE exchange agreement.
Four Corners Generating Station Commitment
------------------------------------------
TEP is a 7% owner of Units 4 and 5 of the Four Corners Generating
Station. The station participation agreement requires that if one of the
participants fails to make its payments for operation of the station when
due, the other station participants must make these payments on behalf of
the defaulting party, in proportion to their ratable ownership interest in
the station, for a period of up to six months. During this time, the
defaulting participant is entitled to its share of the power generated by
the station. After the grace period, the defaulting participant must make
its payments in arrears before it would be entitled to its continuing share
of power.
SCE is a 48% owner of Units 4 and 5 of the station. SCE has publicly
disclosed that due to the high cost of wholesale power in California, which
to date it has not been able to recover from customers, it may no longer be
able to continue to meet its financial obligations. SCE has made all of
its payments for the operation of the station through October 31, 2001.
However, we are uncertain whether SCE will be able to continue to make its
payments for the remainder of 2001. Based on the operating budget for the
station for the year 2001, in the event that SCE were to fail to pay, TEP
may be required to pay on SCE's behalf, for the power SCE receives, an
average amount of $1 million per month for up to six months. TEP is unable
to predict whether it will be required to make any such payments on SCE's
behalf in the future.
REGULATORY MATTERS
------------------
TEP generally uses the same accounting policies and practices used by
unregulated companies for financial reporting under GAAP. However,
sometimes these principles, such as FAS 71, 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 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 cover 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
relating to recovery of TEP's transition costs and standard retail rates,
we discontinued application of FAS 71 to our generation operations.
We continue to apply FAS 71 to the distribution and transmission
portions of TEP's business, our regulated operations. We periodically
assess whether we can continue to apply FAS 71 to these operations. If we
stopped applying FAS 71 to TEP's remaining regulated operations, we would
write off the related balances of TEP's regulatory assets as a charge in
our income statement. Based on the balances of TEP's regulatory assets at
September 30, 2001, if we had stopped applying FAS 71 to TEP's remaining
regulated operations, we would have recorded an extraordinary loss, after
tax, of approximately $247 million. While regulatory orders and market
conditions may affect our cash flows, our cash flows would not be affected
if we stopped applying FAS 71.
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 2000 Form 10-K.
For additional information concerning risk factors, including market
risks, see Safe Harbor for Forward-Looking Statements below.
Commodity Price Risk
--------------------
We are exposed to commodity price risk primarily relating to changes
in the market price of electricity, changes in fuel costs incurred to
generate electricity, and other energy-related products. TEP enters into
forward contracts to buy or sell energy at a specified price at a future
date. These contracts are considered to be derivative commodity
instruments. Generally, TEP commits to future sales based on expected
excess generating capability. However, rather than producing additional
power, TEP may enter into a forward purchase contract to satisfy the
forward sales contract if the market prices are favorable. The forward
sales contracts that are satisfied with forward purchase contracts do not
require any physical delivery of energy by TEP. However, to take advantage
of anticipated market opportunities, TEP is at various times in a net open
position. A net open position means it has either committed to sell more
electricity than it has purchase contracts to cover or it has committed to
purchase more power than it needs for its selling commitments. To limit
exposure to price risk, TEP has trading policies with limits as to total
open positions. TEP continually reviews its trading policies and limits to
respond to the constantly changing market conditions.
TEP measures its market risk related to its commodity exposure by
using a sensitivity analysis. The market prices used to determine fair
value are estimated based on various factors including broker quotes,
exchange prices, over-the-counter prices and time value. As of September
30, 2001, an increase of 10% in the market prices of electric power from
quarter-end levels would have decreased the fair value of its derivative
commodity instruments by less than $1 million. Beginning in 2001, changes
in the fair value of these derivative instruments are measured in our
financial statements in accordance with FAS 133. See Note 2 of Notes to
Financial Statements and Accounting for Derivative Instruments and Hedging
Activities, below.
TEP experienced increased commodity price risk during the third
quarter of 2001, due to a potential need to replace a power resource
previously available to it during the summer peak usage periods. See
Western Energy Markets, SCE Power Exchange Agreement, above. To mitigate
the risk that this resource may be unavailable to TEP, or if other
unexpected losses of generation resources were to occur due to unplanned
outages or natural disasters, TEP purchased alternative sources of capacity
and energy at prices significantly in excess of the cost of these
resources. To the extent possible, TEP also relied upon the new peaking
units which went in-service in June 2001, interruptible contracts, load-
shifting by large mining customers, and reserve sharing arrangements with
other utilities as resources. Under the terms of its Settlement Agreement,
TEP's retail rates are frozen through December 31, 2008, except under
certain circumstances. As such, TEP cannot recover increased purchased
power costs without further ACC action. See Competition, Retail above.
TEP also purchases coal and natural gas in the normal course of
business for fuel for its generating plants. TEP acquires its coal under
long-term coal supply contracts. Purchases of gas historically provided
fuel for only 3-4% of total generation. Beginning in the third quarter of
2000 through June 2001, however, the sustained high levels of wholesale
energy prices in the western U.S. made it profitable for TEP to fuel its
gas-fired generating units more frequently to sell into the wholesale
market. As a result, during the last twelve months, approximately 10-12%
of TEP's generation was fueled by natural gas. Market prices of natural
gas also increased in the latter part of 2000 and the first six months of
2001, before beginning to fall in the third quarter of 2001. These high
market prices, combined with increased gas usage, resulted in gas expense
comprising 30% of total fuel expense in both the third quarter and the
first nine months of 2001. TEP is assured of its gas supply as a retail
customer of the local gas supplier in the region. TEP periodically
negotiates its contract with its gas supplier to establish terms relating
to pricing and scheduling of gas delivery. TEP also entered into two swap
agreements in May 2001 to hedge our risk of fluctuations in the market
price of gas related to approximately a third of our anticipated gas
purchases from June through October 2001. See Results of Operations, Fuel
and Purchased Power Expense, below.
Credit Risk
-----------
UniSource Energy is exposed to credit risk in its energy trading
activities related to potential nonperformance by counterparties. We
manage the risk of counterparty default by performing financial credit
reviews and setting limits and 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 impacted by payment defaults by SCE
and PG&E for amounts owed to the CPX and CISO.
TEP sold approximately $58 million of power to the CPX and CISO during
2000 and $7 million during January of 2001. As a result of payment
defaults by SCE and PG&E, TEP's collection shortfall was approximately $9
million for sales made in 2000 and $7 million for sales made in 2001. We
recorded an allowance for doubtful accounts for the full amount of these
uncollected amounts in the fourth quarter of 2000 and the first quarter of
2001. We recorded no such allowances in years prior to 2000. See Western
Energy Markets, Payment Defaults and Allowances for Doubtful Accounts,
above. Based on a review of its credit exposures at September 30, 2001,
TEP does not anticipate any nonperformance by any of its other
counterparties and did not record any additional reserves in the third
quarter of 2001.
Accounting for Derivative Instruments and Hedging Activities
------------------------------------------------------------
In 1998, the Financial Accounting Standards Board (FASB) issued
Statement of Financial Accounting Standards No. 133 (FAS 133), Accounting
for Derivative Instruments and Hedging Activities. A derivative financial
instrument or other contract derives its value from another investment or
designated benchmark. We buy and sell wholesale power using forward
contracts which are considered to be derivatives. See Note 2 of Notes to
Financial Statements.
On January 1, 2001, we recorded the cumulative effects of adopting FAS
133 in our financial statements by recognizing all derivatives at fair
value and recording the following amounts on our forward contracts as of
January 1, 2001:
Income Statement: after-tax unrealized gain of $470,000.
Balance Sheet:
* Other Comprehensive Income, a component of stockholders' equity:
after-tax unrealized loss of $14 million, and
* Forward Sale and Purchase Contracts Liability of $22 million.
In addition to our forward contracts to buy and sell wholesale power,
we entered into two swap agreements in May 2001 to hedge our risk of
fluctuations in the market price of gas related to approximately a third of
our anticipated gas purchases from June through October 2001. These swaps
are considered derivatives and are designated as cash flow hedges. Under
FAS 133, we record unrealized gains and losses on our forward contracts and
swap agreements and adjust the related asset or liability on a monthly
basis to reflect the market prices at the end of the month. The net
unrealized gain/loss on forward sales and purchases classified as cash flow
hedges is recorded in Other Comprehensive Income, a component of
stockholders' equity. The net unrealized gain/loss on forward sales and
purchases related to TEP's energy trading activity is recorded in Total
Operating Revenues.
In June 2001, the FASB approved a conclusion for FAS 133
Implementation Issue No. C15 (Issue C15), Scope Exceptions: Normal
Purchases and Normal Sales Exception for Option-Type Contracts and Forward
Contracts in Electricity. This guidance provides that power purchase or
sales agreements (i.e. both forward contracts and option contracts),
including capacity contracts, for the purchase or sale of electricity
qualify for the FAS 133 normal purchase and sale exception if certain
criteria are met.
We implemented Issue C15 beginning July 1, 2001, on a prospective
basis, and determined that our contracts classified as cash flow hedges
(excluding the gas swaps discussed above) meet the C15 criteria for the
normal purchases and sales exception. As a result, these cash flow hedge
contracts will continue to be reported on the balance sheet at their fair
values as of June 30, 2001 until settlement of the contracts. All cash
flow hedge contracts open at September 30, 2001, including those that meet
the normal purchases and sales exception under C15, will be settled by
December 31, 2001, and as a result, the unrealized losses included in Other
Comprehensive Income as of September 30, 2001 will be reversed from Other
Comprehensive Income by year-end and realized gains or losses will be
recorded on the income statement.
FUEL SUPPLY
-----------
TEP and its local gas supplier entered into a new Special Gas
Procurement Agreement to replace the agreement that expired on May 31,
2001. This agreement provides for all of TEP's natural gas commodity and
transportation needs for use in power generation and has an initial five
year term. The agreement will automatically continue after the initial
term unless one party gives notice of termination at least 90 days prior to
the anniversary date of the agreement. The ACC approved the agreement,
effective June 28, 2001.
FUTURE GENERATING RESOURCES
---------------------------
TEP
---
TEP determined that additional peaking resources would be needed in
Tucson beginning in 2001 to improve local system reliability. TEP
purchased a 75 MW gas turbine and Millennium purchased a 21 MW gas turbine
(now held by UED and leased to TEP) to address this need. The generators
came online in June to meet summer peaking needs. These units increased
UniSource Energy's net generating capability to approximately 2,000 MW.
TEP's generating needs in the shorter term will be for additional peaking
resources, not for base-load generating capacity. TEP will continue to
add peaking resources in the Tucson area as needed, based upon our
forecasts of retail and firm wholesale load.
UED
---
In recognition of the strong retail growth in Arizona and New Mexico,
as well as existing and projected base-load generation capacity needs in
the western region, we are evaluating the expansion of the coal-fired
Springerville Generating Station by constructing Springerville Units 3 and
4. On October 19, 2001, UED and Salt River Project Agricultural
Improvement and Power District (SRP) signed a joint development agreement
to share ownership and development costs of Springerville Units 3 and 4.
Under the agreement, SRP would also purchase 50% of the power generation
from the facility. The balance of the power generation would be sold to
other regional power companies, possibly including TEP.
Springerville was originally designed for four units. Units 3 and 4
would consist of two 400 MW coal-fired, base-load generating units at the
same site as Springerville Units 1 and 2, and would allow us to spread the
fixed costs of the existing Springerville Common Facilities over two
additional generating units. We are developing the project scope and
schedule and defining the terms of an engineering, procurement, and
construction contract. We are also continuing the permitting process,
evaluating financing plans, and negotiating with potential long-term power
purchasers.
The ACC approved construction of a third and fourth unit at the
Springerville Generating Station in 1977 and 1987, respectively, providing
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. In July 2001, TEP filed an application asking the ACC to
schedule a hearing addressing the need for the fourth electric generating
unit. Evidentiary hearings regarding the need for Unit 4 are scheduled
before the ACC in November 2001. TEP is also currently involved in
discussions with the U.S. Environmental Protection Agency and Arizona
Department of Environmental Quality (ADEQ) to determine specific levels of
acceptable emissions at Springerville. Current plans call for total
emissions from all four units to be less than the emissions from Units 1
and 2 today. The ADEQ has set a public hearing on the air quality control
permit for late November 2001.
Environmental activist groups have expressed concerns regarding the
construction of Units 3 and 4. Such concerns have been expressed in the
permitting and ACC proceedings and may extend to other forums and to issues
apart from the proposed construction. One such group has sent TEP a notice
of intent to sue for alleged violations of the Clean Air Act at the
Springerville Generating Station. The notice alleges 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. TEP believes the claims are
without merit. If legal action were commenced, TEP would vigorously
contest these claims.
We anticipate that power purchase agreements with other project off-
takers and the engineering, procurement and construction contract will be
signed by the fourth quarter of 2001. We expect that construction would
begin by the second quarter of 2002, with commercial operation of Unit 3
expected to occur in early 2005, followed five months later by Unit 4. We
can make no assurances, however, about the ultimate timing, or whether we
will proceed with this project. See also Future Generating Resources,
Millennium in the 2000 Form 10-K.
RESULTS OF OPERATIONS
- ---------------------
UniSource Energy recorded net income of $15.5 million or $0.46 per
average share of Common Stock in the third quarter of 2001 and net income
of $48.1 million or $1.44 per share in the first nine months of 2001. This
compares with net income of $17.2 million or $0.53 per average share of
Common Stock in the third quarter of 2000 and net income of $28.1 million
or $0.87 per share in the first nine months of 2000.
The primary factors affecting the results of operations in the third
quarter of 2001 include a $5.6 million after-tax gain on the sale of a
Millennium subsidiary investment, significantly higher purchased power
expense relating to forward energy purchases to ensure service reliability,
and reduced retail sales and revenues due to relatively mild summer weather
and reduced consumption by mining customers. These factors also affected
the operating results in the first nine months of 2001, but they were
offset by strong results from wholesale marketing activities at TEP during
the first five months of 2001.
Contribution By Business Segment
--------------------------------
The table below shows the contributions to our consolidated after-tax
net income and losses by our three business segments, as well as parent
company expenses and inter-company eliminations, for the third quarter and
first nine months of 2001 and 2000:
Three Months Ended Nine Months Ended
September 30, September 30,
2001 2000 2001 2000
- -------------------------------------------------------------------------------
- Millions of Dollars -
Business Segment
TEP $ 14.4 $ 19.8 $ 56.9 $ 33.1
Millennium 2.1 (1.3) (5.2) (1.2)
UED 0.4 - 0.6 -
Parent Company and Inter-Company
Eliminations (1.4) (1.3) (4.2) (3.8)
- -------------------------------------------------------------------------------
Consolidated Net Income $ 15.5 $ 17.2 $ 48.1 $ 28.1
===============================================================================
Parent Company and Inter-Company Eliminations include the after-tax
interest expense accrued on a note payable from UniSource Energy to TEP.
This note was provided to TEP in exchange for the stock of Millennium in
January 1998. TEP's results include interest income from this note. The
interest expense and interest income are eliminated upon UniSource Energy
consolidation as inter-company transactions. UED's results include rental
income from its turbine lease to TEP. This income, along with TEP's
related rental expense, is also eliminated upon UniSource Energy
consolidation.
TEP's electric utility business accounts for substantially all of
UniSource Energy's assets and revenues. 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 energy
businesses are discussed in Results of Millennium Energy Businesses and
Results of UED below.
New Accounting Standard
-----------------------
On January 1, 2001, we adopted FAS 133, Accounting for Derivative
Instruments and Hedging Activities. As a result, TEP began recognizing
unrealized gains and losses related to forward sale and purchase energy
contracts in its income statement in the first quarter of 2001. The net
unrealized gain/loss on forward sales and purchases related to TEP's energy
trading activity is recorded in Total Operating Revenues. The net
unrealized loss (pre-tax) for the third quarter ended September 30, 2001
was $3 million and the net unrealized gain (pre-tax) for the first nine
months of 2001 was $4 million. See Note 2 of Notes to Financial
Statements.
Beginning July 1, 2001, we implemented, on a prospective basis, FAS
133 Implementation Issue No. C15 (Issue C15), Scope Exceptions: Normal
Purchases and Normal Sales Exception for Option-Type Contracts and Forward
Contracts in Electricity. TEP determined that its contracts classified as
cash flow hedges (excluding the gas swaps) meet the C15 criteria for the
normal purchases and sales exception. As a result, these cash flow hedge
contracts will continue to be reported on the balance sheet at their fair
values as of June 30, 2001 until settlement of the contracts.
The analysis of electric wholesale sales and purchased power costs
below excludes the impact of these unrealized gains and losses required to
be recorded by FAS 133.
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 sales are affected by market prices in the
wholesale energy market, competing sources of energy and capacity in the
region.
TEP experienced a decline in wholesale energy sales, but an increase
in wholesale energy revenues during the third quarter of 2001. Market
demand in the western region declined as a result of cooler temperatures,
and market prices fell as a result of increased capacity in the region,
declining natural gas prices, and the FERC-ordered price mitigation plan
effective June 19, 2001. However, the settlement of energy sales contracts
established when regional market prices were high caused wholesale energy
revenues to increase. In the first nine months of 2001, both TEP's
wholesale energy sales and revenues experienced significant growth,
primarily due to significantly higher regional market prices and
opportunities to sell excess generating capacity to California and other
western wholesale market participants during the first five months of the
year. These revenues more than doubled in the first nine months of 2001
compared with the same period in 2000, and in the nine months ended
September 30, 2001, comprised 53% of total revenues. TEP's electric
wholesale sales consist primarily of four types of sales:
(1) Sales of firm capacity under long-term contracts for periods of more
than one year. TEP currently has long-term contracts with two
entities to sell firm capacity: Salt River Project and the NTUA.
(2) Forward contracts to sell energy for periods of up to one 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 months or one year periods.
Forward contracts may consist of sales of TEP's excess generating
capacity, or may represent trading activity, where forward sales
and purchases may be made within established limits to take
advantage of favorable market opportunities.
(3) Short-term economy energy sales in the daily or hourly markets at
fluctuating spot market prices and other non-firm energy sales,
including sales under a long-term interruptible contract with PDES
entered into by TEP in March 2001.
(4) Sales of transmission service.
Comparisons of TEP's kilowatt-hour sales delivered and the corresponding
electric revenues for the third quarter and first nine months of 2001 are
shown below:
Sales Operating Revenue
- --------------------------------------------------------------------------------------------------
Percent Percent
Three Months Ended September 30, 2001 2000 Change 2001 2000 Change
- --------------------------------------------------------------------------------------------------
- Millions of kWh - - Millions of Dollars -
Electric Retail Sales 2,485 2,515 (1.2%) $ 212.1 $ 214.5 (1.1%)
- --------------------------------------------------------------------------------------------------
Electric Wholesale Sales Delivered:
Long-term Contracts 294 307 (4.2%) 11.1 13.5 (17.8%)
Forward Contracts 819 937 (12.6%) 146.1 67.6 116.1%
Short-term Sales and Other 499 485 2.9% 57.5 42.5 35.3%
Transmission - - - 1.5 1.1 36.4%
- --------------------------------------------------------------------------------------------------
Total Electric Wholesale Sales 1,612 1,729 (6.8%) 216.2 124.7 73.4%
- --------------------------------------------------------------------------------------------------
Total 4,097 4,244 (3.5%) $ 428.3 $ 339.2 26.3%
==================================================================================================
Sales Operating Revenue
- --------------------------------------------------------------------------------------------------
Percent Percent
Nine Months Ended September 30, 2001 2000 Change 2001 2000 Change
- --------------------------------------------------------------------------------------------------
- Millions of kWh - - Millions of Dollars -
Electric Retail Sales 6,373 6,364 0.1% $ 518.4 $ 518.7 (0.1%)
- --------------------------------------------------------------------------------------------------
Electric Wholesale Sales Delivered:
Long-term Contracts 933 895 4.2% 38.1 39.5 (3.5%)
Forward Contracts 2,490 1,777 40.1% 348.3 91.6 280.2%
Short-term Sales and Other 1,678 1,775 (5.5%) 196.1 96.8 102.6%
Transmission - - - 3.6 2.8 28.6%
- --------------------------------------------------------------------------------------------------
Total Electric Wholesale Sales 5,101 4,447 14.7% 586.1 230.7 154.1%
- --------------------------------------------------------------------------------------------------
Total 11,474 10,811 6.1% $1,104.5 $ 749.4 47.4%
==================================================================================================
TEP's kWh sales to retail customers decreased 1.2% in the third
quarter of 2001 compared with the same period in 2000, despite a 2.4%
increase in retail customers. Sales to mining customers decreased by 19%,
offset, in part, by increased sales to residential and commercial
customers. The decrease in mining consumption is due to cutbacks in
production by one of our mining customers in response to supply and demand
factors in the world copper market and reductions in demand for copper.
Milder summer temperatures caused a 5% decrease in Cooling Degree Days for
the quarter, from 1,019 days to 969 days. Retail revenues also decreased
slightly in the third quarter of 2001 compared with the same period in
2000, reflecting the decreased kWh sales and the reversal in 2000 of a $2.5
million reserve for disputed charges. These quarter-to-quarter decreases
were offset by higher kWh sales and revenues in the first quarter of 2001,
leaving retail kWh sales and revenues for the first nine months of 2001
virtually unchanged when compared with the same period in 2000.
Kilowatt-hour electric wholesale sales decreased by 7% in the third
quarter of 2001 compared with 2000, while revenues from electric wholesale
sales increased by 73% in the same period. The increase in revenues
resulted from the settlement of sales under forward contracts that were
established when market prices were higher earlier in the year. For the
first nine months of 2001, kilowatt-hour electric wholesale sales increased
by 15% and the sales revenues increased by 154%, compared with the same
period in 2000, with the largest increase in sales under forward contracts.
The higher volumes and revenues under forward contracts in the first nine
months represent increased purchase and resale transactions. Short-term
economy sales in the daily and hourly markets at higher market prices made
it economical for TEP to run its gas generation units to produce energy to
sell to other regional utilities and marketers during the first six months
of 2001. Factors contributing to the higher market prices included
increased demand due to population and economic growth in the region,
higher natural gas prices, dysfunction in the California marketplace,
increased maintenance outages due to higher than normal operating levels,
lower availability of hydropower resources, transmission constraints, and
environmental constraints.
Fuel and Purchased Power Expenses
---------------------------------
Fuel expense at TEP's generating plants decreased by $5 million, or
6%, in the quarter ended September 30, 2001 compared with the same quarter
in 2000, primarily because of decreased usage of gas generation and forced
outages at the Springerville Generating Station. The average cost of fuel
per kWh generated was 2.17 cents for both the third quarter 2001 and 2000.
For the nine months ended September 30, 2001, Fuel expense increased $38
million, or 23%, due to increased gas consumption to meet increased kWh
sales. This includes gas expense for the new gas-fired peaking units,
which went in-service in June 2001, and the approximately $5 million
additional cost associated with the gas swap agreements we entered into in
May 2001. See Market Risks, Commodity Price Risk, above. The average cost
of fuel per kWh generated for the first nine months of 2001 and 2000 was
2.23 cents and 1.90 cents, respectively.
Purchased Power expense increased by $115 million, or 119%, in the
third quarter of 2001 over the same period in 2000 due principally to
increased purchases in the forward and spot energy markets to resell to
wholesale customers. This increased expense included the settlement of
wholesale energy purchase contracts, which were established when forward
power prices were higher. Purchased Power expense was also impacted by
several forward purchase contracts we entered into in May 2001 to assure
service reliability in the summer months and to mitigate the risk of the
potential loss of 110 MW under an exchange agreement with SCE. See SCE
Power Exchange Agreement, above. The additional cost to assure service
reliability was approximately $12 million. For the nine months ended
September 30, 2001, Purchased Power expense increased $276 million, a 170%
increase over the same period in 2000.
TEP recorded a $13 million pre-tax ($8 million after-tax) one-time
charge in the third quarter of 2000 as a result of a coal supply contract
amendment related to the San Juan Generating Station.
Other Operating Expenses
------------------------
Other Operations and Maintenance expense was unchanged for the third
quarter 2001 compared with the same period in 2000. Other Operations and
Maintenance expense increased $15 million, or 13%, for the first nine
months of 2001 compared with the first nine months of 2000 primarily due to
$7 million in bad debt reserves recorded in the first quarter of 2001, a $3
million increase in Maintenance expense, and a $3 million increase in
various other production expenses. We recorded the $7 million in reserves
to cover our credit exposure for risk of non-payment from electric
wholesale sales to California made in January 2001. See Note 6 of Notes to
Financial Statements. The higher Maintenance expense is the result of
scheduled maintenance at the Irvington, Springerville Unit 2 and San Juan
generating plants in the first quarter of 2001.
Amortization of the Transition Recovery Assets increased $3 million,
or 21%, in the first nine months of 2001 compared with the same period in
2000 due to increased kWh sales.
Income Taxes decreased $2 million in the third quarter of 2001
compared with the same period in 2000 due to decreased pre-tax income.
Income Taxes increased $29 million in the first nine months compared with
the same period in 2000 due to higher pre-tax income and the recognition of
$6 million in tax benefits in the second quarter of 2000 from the
resolution of various IRS audit issues. See Note 7 of Notes to Financial
Statements.
Other Income (Deductions)
-------------------------
TEP's income statements for the quarters ended September 30, 2001 and
2000 each include $2 million of interest income 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 inter-company transaction.
Other interest income for the quarter and nine months ended September
30, 2001 was higher than the same periods in 2000 due to higher average
cash balances and increased interest income on investments in Springerville
Unit 1 Lease debt. See Liquidity and Capital Resources below.
Other income for the first nine months of 2001 also included a $1
million pre-tax gain from the sale of real estate in April 2001.
Interest Expense
----------------
Interest Expense for the third quarter and first nine months of 2001
decreased by $1 million and $5 million, respectively, compared with the same
periods in 2000. These reductions were primarily due to lower amortization
of losses on reacquired debt, decreases in the average interest rate on
long-term variable rate tax-exempt debt in 2001, and debt maturities in
2000.
RESULTS OF MILLENNIUM ENERGY BUSINESSES
- ---------------------------------------
The table below provides a breakdown of the after-tax net income and
losses recorded by the Millennium Energy Businesses for the quarter and
nine months ended September 30, 2001 compared with the same periods in
2000.
Three Months Ended Nine Months Ended
September 30, September 30,
2001 2000 2001 2000
- -------------------------------------------------------------------------------
- Millions of Dollars -
Energy Technology Investments $ (3.0) $ (1.5) $ (10.8) $ (3.3)
Nations Energy 5.2 (0.3) 5.0 0.6
Other (0.1) 0.5 0.6 1.5
- -------------------------------------------------------------------------------
Total Millennium $ 2.1 $ (1.3) $ (5.2) $ (1.2)
===============================================================================
Energy Technology Investments
-----------------------------
Millennium's Energy Technology Investments include Global Solar,
Infinite Power Solutions, MicroSat and ITN. Millennium recorded an after-
tax net loss of $3.0 million related to its Energy Technology Investments
in the third quarter and an after-tax net loss of $10.8 million for the
first nine months of 2001. The major factors contributing to these losses
are Global Solar's increased development efforts of its solar modules and
Infinite Power Solutions' expenditures to develop thin-film, solid-state
rechargeable batteries. See Note 3 of Notes to Financial Statements.
Nations Energy
--------------
Nations Energy recorded an after-tax net profit of $5.2 million in the
third quarter and $5.0 million in the first nine months of 2001. This
compares with a small net loss in the three months and the small net gain
in the nine months ended September 30, 2000. The sale of Nations Energy's
investment in a power project in Curacao in September 2001 resulted in an
after-tax gain of $5.6 million. Nations Energy's earnings in the first
nine months of 2000 included a $1.5 million after-tax gain on the sale of a
minority interest in a power project in the Czech Republic, offset by a
$1.5 million after-tax decrease in the market value of its Panama
investment.
Other Millennium Investments
----------------------------
The results in the "Other" line item in the third quarter and first
nine months of 2001 relate primarily to after-tax earned interest of $0.2
million and $1.0 million, respectively, offset by Millennium's standalone
results of operations and immaterial losses on its other investments. The
net gain in the third quarter and first nine months of 2000 reflects after-
tax interest income on Millennium investments.
RESULTS OF UED
- --------------
UED was established in February 2001 and owns a 21 MW gas turbine,
which it leases to TEP under an operating lease. UED recorded a net profit
of $0.4 million for the quarter ended September 30, 2001. UED's income
represents rental income, less expenses, under the operating lease with
TEP. This rental income is eliminated from UniSource Energy after-tax
earnings as an inter-company transaction. UED is also the entity that is
engaging in the proposed expansion of the Springerville Generating Station
by constructing Springerville Units 3 and 4. Development costs related to
that project are currently being capitalized and total approximately $3.2
million at September 30, 2001.
DIVIDENDS ON COMMON STOCK
- -------------------------
UniSource Energy
----------------
On August 2, 2001, UniSource Energy declared a cash dividend in the
amount of $0.10 per share on its Common Stock. This dividend, totaling
approximately $3 million, was paid September 10, 2001 to shareholders of
record at the close of business August 15, 2001. On November 2, 2001,
UniSource Energy declared a cash dividend in the amount of $0.10 per share
on its Common Stock, payable December 10, 2001 to shareholders of record at
the close of business November 15, 2001.
UniSource Energy's Board of Directors reviews our dividend policy 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
and Millennium.
TEP
---
In December 2000, TEP declared and paid a dividend of $30 million to
UniSource Energy.
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 September 30,
2001, the required minimum net worth was $256 million. TEP's actual net
worth at September 30, 2001 was $352 million. As of September 30, 2001,
TEP was in compliance with the terms of the Credit Agreement. See
Investing and Financing Activities, TEP Credit Agreement, below.
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 equity ratio
equals 37.5% of total capital (excluding capital lease obligations). As of
September 30, 2001, TEP's equity ratio on that basis was 23.8%.
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 2000 dividend from 2000
earnings since TEP had an accumulated deficit, rather than positive
retained earnings.
LIQUIDITY AND CAPITAL RESOURCES
- -------------------------------
CASH FLOWS
----------
UniSource Energy
----------------
Consolidated cash and cash equivalents increased from the September
30, 2000 balance of $103 million to $191 million at September 30, 2001.
For the twelve-month period ended September 30, 2001, cash generated from
operating activities exceeded consolidated net cash outflows for investing
and financing.
Net cash flows from operating activities increased by $17 million in
the first nine months of 2001 compared with the same period in 2000. The
net increase resulted primarily from the following factors:
* $62 million increase in cash receipts from sales to wholesale and
retail customers, net of increased fuel and purchased power costs
paid and
* $11 million decrease in capital lease interest paid; offset by
* $30 million increase in income taxes paid and
* $26 million increase in other operations and maintenance costs paid.
Net cash used for investing activities totaled $94 million during the
first nine months of 2001 compared with $82 million during the same period
in 2000. Capital expenditures were $17 million higher in 2001, and
included $16 million incurred by UED in relation to the purchase of a gas
turbine, which was placed in-service in June 2001. Investments in and
loans to Millennium Energy Businesses also increased by $12 million, offset
by (i) $5 million in proceeds from the sale of Nations Energy's interest in
the Curacao project, (ii) $11 million in proceeds from the final payment of
a promissory note from NewEnergy to MEH, and (iii) $7 million in proceeds
from the sale of real estate in 2001. Significant investing activities in
2000 included: (i) the $28 million purchase of Springerville Unit 1 Lease
Debt by Millennium, (ii) Nations Energy's $20 million in proceeds from the
sale of its interest in the Czech Republic power project, and (iii) $11
million in proceeds from the first payment of a promissory note by
NewEnergy to MEH.
Net cash used for financing activities totaled $30 million in the
first nine months of 2001 compared with $95 million during the same period
in 2000. In 2001, TEP retired $26 million in capital lease obligations
when due and UniSource Energy paid $10 million in dividends. In 2000, TEP
retired $47 million of its maturing 12.22% Series First Mortgage Bonds and
$39 million in capital lease obligations, and UniSource Energy paid $8 million
in dividends.
UniSource Energy's consolidated cash balance, including cash
equivalents, at November 5, 2001 was approximately $213 million. We invest
cash balances in high-grade money market securities with an emphasis on
preserving the principal amounts invested.
TEP
---
Cash and cash equivalents increased from the September 30, 2000
balance of $64 million to $156 million at September 30, 2001. For the
twelve-month period ended September 30, 2001, net cash inflows from
operating activities exceeded net cash outflows from investing and
financing activities.
The reasons for the changes in TEP's statement of cash flows are
incorporated above in the analysis of the changes in UniSource Energy's
consolidated cash flows. In addition, TEP invested an additional $2
million in Springerville Unit 1 Lease Debt. TEP purchased these notes from
Millennium in July 2001 and, as a result, Millennium no longer holds any
lease debt.
TEP's consolidated cash balance, including cash equivalents, at
November 5, 2001 was approximately $168 million.
TEP expects to generate enough cash flow during the next 12 months to
fund continuing operating activities, capital expenditures, required debt
maturities, and to pay dividends to UniSource Energy. However, TEP's cash
flows may vary due to changes in wholesale market conditions, changes in
short-term interest rates and other factors. If cash flows were to fall
short of our expectations, or if monthly cash requirements temporarily
exceed available cash balances, TEP would borrow from the Revolving Credit
Facility.
INVESTING AND FINANCING ACTIVITIES
- ----------------------------------
UniSource Energy
----------------
During the next 12 months, UniSource Energy expects to use cash to
fund investments in Millennium's and UED's unregulated energy businesses
and to pay dividends to shareholders. We expect our sources of cash to be
dividends from our subsidiaries, primarily TEP. Although no specific
offerings are currently contemplated, UniSource Energy may also issue debt
and/or equity securities from time to time. If available cash falls short
of expectations, we would reevaluate the investment requirements of
Millennium's unregulated energy businesses and/or seek additional financing
for, or investments in, those businesses by unrelated parties.
TEP
---
Capital Expenditures
--------------------
TEP's capital expenditures for the three months and nine months ended
September 30, 2001 were $23 million and $79 million, respectively. TEP's
capital expenditures forecasted for the year ending December 31, 2001 is
approximately $99 million. These authorized expenditures include costs for
TEP to comply with current federal and state environmental regulations.
All of these estimates are subject to continuing review and adjustment.
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.
In January 2001, TEP and Citizens Communications Company entered into
a project development agreement for the construction of a transmission line
from Tucson to Nogales, Arizona. TEP presented environmental impact
testimony to the Arizona Power Plant and Transmission Line Siting Committee
(Siting Committee) as a first step towards gaining approval for the
location of the line. Several hearings with the Siting Committee were
held, and on October 4, 2001, TEP was granted a Certificate of Environmental
Compliance (Certificate), with certain conditions, pending ACC approval.
The ACC has sixty days to confirm, deny, or modify the Certificate. The
proposed line is planned to be in-service by December 31, 2003 with
construction costs estimated to be about $70 million. This project could
provide an opportunity for TEP to interconnect with Mexico, providing
further reliability and market opportunities in the region.
The estimated expenditures of $99 million for the year 2001 do not
include any amounts for the new transmission line described above, or for
the potential expansion of the Springerville Generating Station.
Springerville generation expenditures are expected to be made by UED. See
Investing and Financing Activities, UED, below.
TEP Credit Agreement
--------------------
As of September 30, 2001 and as of November 5, 2001, TEP had no
borrowings outstanding under its $100 million Revolving Credit Facility.
TEP is required by its Credit Agreement to maintain certain financial
covenants including (a) a minimum Consolidated Tangible Net Worth equal to
the sum of $133 million plus 40% of cumulative Consolidated Net Income
since January 1, 1997, (b) a minimum Cash Coverage Ratio ranging from 1.50
in 2001 and increasing to 1.55 in 2002, and (c) a maximum Leverage Ratio
ranging from 6.40 in 2001 and decreasing to 6.20 in 2002. TEP is in
compliance with each of these covenants.
Millennium -- Unregulated Energy Businesses
-------------------------------------------
Millennium is an unregulated subsidiary that invests in emerging
energy production and various energy-related technologies and businesses.
Below we provide an update on our significant investments, commitments and
investment proceeds in the quarter ended September 30, 2001 and the first
nine months of 2001.
Sale of NewEnergy, Inc.
-----------------------
On July 23, 1999, MEH sold its 50% ownership in NewEnergy to the AES
Corporation for approximately $50 million in consideration. As part of the
transaction, two promissory notes were issued by NewEnergy totaling $22.8
million. One of the promissory notes in the principal amount $11.4 million
was paid on July 24, 2000 and the remaining promissory note for $11.4
million was paid on July 23, 2001.
Investments in Energy Technologies
----------------------------------
Under a September 2000 agreement reached with INICA, Millennium agreed
to certain equity and credit commitments:
* a $20 million credit line to Global Solar,
* a $6 million credit line to Infinite Power Solutions,
* a $10 million equity commitment and a $10 million credit line to
MicroSat, and
* a $3 million equity commitment and a $1 million credit line to the
product development subsidiary, now called ITN Energy Systems, Inc.
As of September 30, 2001, Millennium had funded approximately $20
million of its combined $26 million commitment to Global Solar and Infinite
Power Solutions, $16 million of which was funded during 2001. In the nine
months ended September 30, 2001, Millennium provided $10 million in equity
funding to MicroSat. MicroSat had not drawn against its $10 million credit
line as of September 30, 2001. Millennium is evaluating its strategy and
options in its MicroSat investment. In July 2001, Millennium completed
funding its $3 million equity commitment to ITN Energy Systems, Inc. and,
as of September 30, 2001, $0.5 million has been drawn against the $1
million line of credit. Millennium expects to fund approximately $7
million to its various Energy Technology Investments in the fourth quarter
of 2001. A significant portion of the funding under these agreements will
be used for research and development purposes, establishment of the
production line, and other administrative costs. We recognize expense as
these funds are expended for administrative and research and development
purposes. Additional investment commitments may be made to these technology
investments depending on their funding requirements and business outlook.
Nations Energy Commitments
--------------------------
In September 2001, Nations Energy, a wholly-owned subsidiary of
Millennium, recorded an after-tax gain of $5.6 million from the sale of its
26% equity interest in a power project located in Curacao, Netherland
Antilles. Nations Energy received $5 million in cash proceeds and recorded
an $8 million note receivable from the sale. The note receivable was
recorded at net present value and payments are expected as follows: $2
million in July 2004, $4 million in July 2005, and $5 million in July 2006.
In addition, in October 2001, Nations Energy's $5 million deposit to fund
scheduled equity contributions through April 2003 and $10 million deposit
for possible construction overruns were returned to Nations Energy.
After the sale of the Nations Curacao power project, Nations'
remaining investment is a minority interest investment in a project in
Panama. At September 30, 2001, Nations Energy's investment in this project
was $1 million. Currently, we do not intend to make any material
investments in new projects through Nations Energy and we continue to
review options for the sale of Nations Energy's remaining investment.
Other Investments and Commitments
---------------------------------
In July 2000, Millennium made a $15 million capital commitment to a
limited partnership which will fund energy-related investments. As of
September 30, 2001, Millennium has funded $6 million under this commitment,
$4 million of which was funded in 2001. The remaining $9 million is
expected to be invested within two to three years. Millennium recognized
after-tax investment earnings from the partnership of approximately $0.4
million in the nine months ended September 30, 2001. A member of the
UniSource Energy Board of Directors has a minor investment in the project.
An affiliate of this board member serves as the general partner.
In November 2000, Millennium made a $5 million capital commitment to a
venture capital fund that will focus on information technology, optics and
biotechnology in Tucson, Arizona. A member of the UniSource Energy Board
of Directors owns the company that manages the fund. As of September 30,
2001, Millennium had paid approximately $0.3 million, including funding
under its commitment and organizational and management expenses related to
the fund. Millennium expects to fund approximately $1 million under this
agreement in 2001.
In August 2001, Millennium invested $3 million in Powertrusion
International Inc. (Powertrusion), a company that has developed
technologies to produce lightweight fiberglass utility poles. The
investment provided Millennium a controlling 50.5% interest in the company.
Maintaining control of Powertrusion will depend upon many factors,
including providing an additional $2 million in contingent consideration by
August 2002. Contribution of the contingent additional investment is
solely determined by Millennium.
UED
---
We are evaluating the expansion of the coal-fired Springerville
Generating Station by constructing Springerville Units 3 and 4. On October
19, 2001, UED and SRP signed a joint development agreement to share
ownership and development costs of Springerville Units 3 and 4. Under the
agreement, SRP would also purchase 50% of the power generation from the
facility. The balance of the power generation would be sold to other
regional power companies, possibly including TEP.
Springerville was originally designed for four units. Units 3 and 4
would consist of two 400 MW coal-fired, base-load generating units at the
same site as Springerville Units 1 and 2, and would allow us to spread the
fixed costs of the existing Springerville Common Facilities over the two
additional generating units. We are developing the project scope and
schedule and defining the terms of an engineering, procurement, and
construction contract. We are also continuing the permitting process,
evaluating financing plans, and negotiating with potential long-term power
purchasers.
Environmental activist groups have expressed concerns regarding the
construction of Units 3 and 4. Such concerns have been expressed in the
permitting and ACC proceedings and may extend to other forums and to issues
apart from the proposed construction. One such group has sent TEP a notice
of intent to sue for alleged violations of the Clean Air Act at the
Springerville Generating Station. The notice alleges 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. TEP believes the claims are
without merit. If legal action were commenced, TEP would vigorously
contest these claims.
We anticipate that power purchase agreements with other project off-
takers and the engineering, procurement and construction contract will be
signed by the fourth quarter of 2001. Construction is expected to begin by
the second quarter of 2002, with commercial operation of Unit 3 expected to
occur in early 2005, followed five months later by Unit 4. Total
construction costs for this project are expected to range from $900 million
to $1 billion from 2002 to 2005, and total project costs, which include
construction costs, various development costs and interest during
construction, are expected to exceed $1.2 billion. We can make no
assurances, however, about the ultimate timing, or whether we will proceed
with this project.
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 West, including
hydroelectric resources, weather, natural gas prices and the impact
of utility restructuring and generation divestitures in various
states, as well as federal price controls.
5. The creditworthiness of the entities to which TEP sells capacity and
energy.
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 financings and rate structures.
8. Changes affecting the cost of competing energy alternatives,
including changes in available generating technologies and changes
in the cost of natural gas.
9. Changes in accounting principles or the application of such principles
to UniSource Energy or TEP.
10. Market conditions and technological changes affecting UniSource
Energy's unregulated businesses.
- -------------------------------------------------------------------------------
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's and TEP's Annual Report on Form 10-K for the year ended December
31, 2000, 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.
PART II - OTHER INFORMATION
ITEM 1. - LEGAL PROCEEDINGS
- -------------------------------------------------------------------------------
None.
ITEM 5. - OTHER INFORMATION
- -------------------------------------------------------------------------------
ADDITIONAL FINANCIAL DATA
The following table reflects the ratio of earnings to fixed charges for
TEP:
9 Months Ended 12 Months Ended
September 30, Ended September 30,
2001 2001
-------------- -------------------
Ratio of Earnings to Fixed Charges 1.76 1.88
ITEM 6. - EXHIBITS AND REPORTS ON FORM 8-K
- -------------------------------------------------------------------------------
(a) Exhibits.
-- See Exhibit Index.
(b) Reports on Form 8-K.
None.
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: November 13, 2001 /s/ Kevin Larson
----------------------------
Kevin Larson
Vice President and Principal
Financial Officer
TUCSON ELECTRIC POWER COMPANY
-----------------------------
(Registrant)
Date: November 13, 2001 /s/ Kevin Larson
-----------------------------
Kevin Larson
Vice President and Principal
Financial Officer
EXHIBIT INDEX
11 - Statement re: computation of per share earnings - UniSource
Energy.
12 - Computation of Ratio of Earnings to Fixed Charges - TEP.
15 - Letter regarding unaudited interim financial information.