FORM 10-Q
Securities and Exchange Commission
Washington, D.C. 20549
[X] QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE
ACT OF 1934
For the quarterly period ended September 30, 1998
----------------------------
OR
[ ] TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES
EXCHANGE ACT OF 1934
For the transition period from to
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Commission file number 1-8962
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PINNACLE WEST CAPITAL CORPORATION
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(Exact name of registrant as specified in its charter)
ARIZONA 86-0512431
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(State or other jurisdiction of (I.R.S. Employer
incorporation or organization) Identification No.)
400 E. VAN BUREN ST., P.O. BOX 52132, PHOENIX, ARIZONA 85072-2132
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(Address of principal executive offices) (Zip Code)
Registrant's telephone number, including area code: (602) 379-2500
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(Former name, former address and former fiscal year,
if changed since last report)
Indicate by check mark whether the registrant (1) has filed all reports required
to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during
the preceding 12 months (or for such shorter period that the registrant was
required to file such reports), and (2) has been subject to such filing
requirements for the past 90 days.
Yes [X] No [ ]
Indicate the number of shares outstanding of each of the issuer's classes of
common stock, as of the latest practicable date.
Number of shares of common stock, no par value,
outstanding as of November 12, 1998: 84,733,212
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GLOSSARY
ACC - Arizona Corporation Commission
ACC Staff - Staff of the Arizona Corporation Commission
APS - Arizona Public Service Company
Company - Pinnacle West Capital Corporation
EITF - Emerging Issues Task Force
EITF 97-4 - Emerging Issues Task Force Issue No. 97-4, "Deregulation of the
Pricing of Electricity --- Issues Related to the Applications of FASB Statements
No. 71, Accounting for the Effects of Certain Types of Regulation, and No. 101,
Regulated Enterprises --- Accounting for the Discontinuation of Application of
FASB Statement No. 71"
El Dorado - El Dorado Investment Company
FERC - Federal Energy Regulatory Commission
ITC - Investment tax credit
1997 10-K - Pinnacle West Capital Corporation Annual Report on Form 10-K for the
fiscal year ended December 31, 1997
Palo Verde - Palo Verde Nuclear Generating Station
Pinnacle West - Pinnacle West Capital Corporation
Power Coordination Agreement - 1955 agreement between the Company and Salt River
Project that provides for certain electric system and power sales
SFAS No. 71 - Statement of Financial Accounting Standards No. 71, "Accounting
for the Effects of Certain Types of Regulation"
SFAS No. 128 - Statement of Financial Accounting Standards No. 128, "Earnings
Per Share"
SFAS No. 131 - Statement of Financial Accounting Standards No. 131, "Disclosures
about Segments of an Enterprise and Related Information"
SFAS No. 133 - Statement of Financial Accounting Standards No. 133, "Accounting
for Derivative Instruments and Hedging Activities"
Salt River Project - Salt River Project Agricultural Improvement and Power
District
SunCor - SunCor Development Company
TEP - Tucson Electric Power Company
Territorial Agreement - 1955 agreement between APS and Salt River Project that
has provided exclusive retail service territories in Arizona as against each
other
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PART I. FINANCIAL INFORMATION
ITEM 1. FINANCIAL STATEMENTS.
PINNACLE WEST CAPITAL CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
-------------------------------------------
(Unaudited)
(Dollars in thousands, except per share amounts)
Three Months Ended
September 30,
1998 1997
------------ ------------
Operating Revenues
Electric $ 740,734 $ 632,821
Real estate 18,276 30,929
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Total 759,010 663,750
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Fuel Expenses
Fuel for electric generation 74,112 48,379
Purchased power 178,587 110,151
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Total 252,699 158,530
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Operating Expenses
Utility operations and maintenance 110,259 110,102
Real estate operations 18,821 29,487
Depreciation and amortization 94,981 91,594
Taxes other than income taxes 30,412 30,583
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Total 254,473 261,766
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Operating Income 251,838 243,454
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Other Income (Deductions)
Interest on long-term debt (37,733) (41,763)
Other interest (4,313) (4,403)
Capitalized interest 4,731 4,985
Preferred stock dividend requirements of APS (2,347) (2,984)
Other-net (1,511) 1,937
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Total (41,173) (42,228)
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Income Before Income Tax 210,665 201,226
Income Tax Expense 83,384 76,886
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Net Income $ 127,281 $ 124,340
============ ============
Average Common Shares Outstanding 84,769,615 84,747,949
Earnings Per Average Common Share Outstanding:
Net income - basic $ 1.50 $ 1.47
Net income - diluted $ 1.49 $ 1.46
Dividends Declared Per Share $ -- $ --
============ ============
See Notes to Condensed Consolidated Financial Statements.
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PINNACLE WEST CAPITAL CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
-------------------------------------------
(Unaudited)
(Dollars in thousands, except per share amounts)
Nine Months Ended
September 30,
1998 1997
------------ ------------
Operating Revenues
Electric $ 1,562,872 $ 1,470,593
Real estate 81,353 80,638
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Total 1,644,225 1,551,231
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Fuel Expenses
Fuel for electric generation 174,874 155,127
Purchased power 247,327 188,182
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Total 422,201 343,309
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Operating Expenses
Utility operations and maintenance 309,388 287,280
Real estate operations 75,270 77,550
Depreciation and amortization 281,396 276,005
Taxes other than income taxes 90,690 91,138
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Total 756,744 731,973
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Operating Income 465,280 475,949
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Other Income (Deductions)
Interest on long-term debt (116,015) (123,283)
Other interest (11,394) (14,877)
Capitalized interest 14,261 14,995
Preferred stock dividend requirements of APS (7,660) (9,805)
Other-net 3,040 10,983
------------ ------------
Total (117,768) (121,987)
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Income Before Income Tax 347,512 353,962
Income Tax Expense 140,148 137,058
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Net Income $ 207,364 $ 216,904
============ ============
Average Common Shares Outstanding 84,788,514 85,764,317
Earnings Per Average Common Share Outstanding:
Net income - basic $ 2.45 $ 2.53
Net income - diluted $ 2.43 $ 2.51
Dividends Declared Per Share $ 0.900 $ 0.825
============ ============
See Notes to Condensed Consolidated Financial Statements.
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PINNACLE WEST CAPITAL CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
-------------------------------------------
(Unaudited)
(Dollars in thousands, except per share amounts)
Twelve Months Ended
September 30,
1998 1997
------------ ------------
Operating Revenues
Electric $ 1,970,832 $ 1,850,047
Real estate 117,188 106,090
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Total 2,088,020 1,956,137
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Fuel Expenses
Fuel for electric generation 221,088 217,654
Purchased power 294,431 207,115
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Total 515,519 424,769
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Operating Expenses
Utility operations and maintenance 421,542 429,569
Real estate operations 109,348 101,881
Depreciation and amortization 373,676 366,091
Taxes other than income taxes 121,098 118,475
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Total 1,025,664 1,016,016
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Operating Income 546,837 515,352
------------ ------------
Other Income (Deductions)
Allowance for equity funds used during
construction -- (411)
Interest on long-term debt (156,897) (164,389)
Other interest (15,190) (20,770)
Capitalized interest 18,969 18,680
Preferred stock dividend requirements of APS (10,658) (13,941)
Other-net (3,374) 3,820
------------ ------------
Total (167,150) (177,011)
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Income From Continuing Operations Before
Income Tax 379,687 338,341
Income Tax Expense 153,371 128,097
------------ ------------
Income From Continuing Operations 226,316 210,244
Loss on Discontinued Operations, Net of Income
Tax of $6,461 -- (9,539)
============ ============
Net Income $ 226,316 $ 200,705
============ ============
Average Common Shares Outstanding 84,773,062 86,190,582
Earnings Per Average Common Share Outstanding:
Continuing operations - basic $ 2.67 $ 2.44
Net income - basic $ 2.67 $ 2.33
Continuing operations - diluted $ 2.66 $ 2.43
Net income - diluted $ 2.66 $ 2.32
Dividends Declared Per Share $ 1.200 $ 0.825
============ ============
See Notes to Condensed Consolidated Financial Statements.
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PINNACLE WEST CAPITAL CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS
-------------------------------------
(Unaudited)
ASSETS
------
(Thousands of Dollars)
September 30, December 31,
1998 1997
------------ -------------
Current Assets
Cash and cash equivalents $ 30,126 $ 27,484
Customer and other receivables--net 295,701 183,507
Accrued utility revenues 86,153 58,559
Material and supplies 71,896 70,634
Fossil fuel 17,303 9,621
Deferred income taxes 23,380 57,887
Other current assets 47,056 41,408
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Total current assets 571,615 449,100
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Investments and Other Assets
Real estate investments--net 348,255 365,921
Other assets 234,025 215,027
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Total investments and other assets 582,280 580,948
----------- -----------
Utility Plant
Electric plant in service and held for
future use 7,179,571 7,009,059
Less accumulated depreciation and
amortization 2,759,425 2,620,607
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Total 4,420,146 4,388,452
Construction work in progress 211,758 237,492
Nuclear fuel, net of amortization 55,771 51,624
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Net utility plant 4,687,675 4,677,568
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Deferred Debits
Regulatory asset for income taxes 414,491 458,369
Rate synchronization cost deferrals 317,463 358,871
Other deferred debits 337,988 325,561
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Total deferred debits 1,069,942 1,142,801
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Total Assets $ 6,911,512 $ 6,850,417
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See Notes to Condensed Consolidated Financial Statements.
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PINNACLE WEST CAPITAL CORPORATION
CONDENSED CONSOLIDATED BALANCE SHEETS
-------------------------------------
(Unaudited)
LIABILITIES AND EQUITY
----------------------
(Thousands of Dollars)
September 30, December 31,
1998 1997
------------ ------------
Current Liabilities
Accounts payable $ 178,659 $ 117,429
Accrued taxes 206,213 84,610
Accrued interest 28,072 32,974
Short-term borrowings 115,350 130,750
Current maturities of long-term debt 158,077 108,695
Customer deposits 30,820 30,672
Other current liabilities 34,492 18,534
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Total current liabilities 751,683 523,664
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Long-Term Debt Less Current Maturities 2,054,473 2,244,248
----------- -----------
Deferred Credits and Other
Deferred income taxes 1,310,917 1,363,461
Deferred investment tax credit 30,576 50,861
Unamortized gain - sale of utility plant 78,931 82,363
Other 394,890 387,223
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Total deferred credits and other 1,815,314 1,883,908
----------- -----------
Minority Interests
Non-redeemable preferred stock of APS 123,795 142,051
----------- -----------
Redeemable preferred stock of APS 9,401 29,110
----------- -----------
Commitments and contingencies (Notes 5 and 8)
Common Stock Equity
Common stock, no par value 1,552,128 1,553,771
Retained earnings 604,718 473,665
----------- -----------
Total common stock equity 2,156,846 2,027,436
----------- -----------
Total Liabilities and Equity $ 6,911,512 $ 6,850,417
=========== ===========
See Notes to Condensed Consolidated Financial Statements.
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PINNACLE WEST CAPITAL CORPORATION
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
-----------------------------------------------
(Unaudited)
(THOUSANDS OF DOLLARS)
Nine Months Ended
September 30,
1998 1997
--------- ---------
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income $ 207,364 $ 216,904
Items not requiring cash
Depreciation and amortization 307,148 300,698
Deferred income taxes--net (11,533) (17,740)
Deferred investment tax credit (20,285) (21,007)
Other--net 284 (5,017)
Changes in current assets and liabilities
Customer and other receivables--net (112,194) (86,483)
Accrued utility revenues (27,594) (26,597)
Materials, supplies and fossil fuel (8,944) 2,077
Other current assets (5,648) (1,898)
Accounts payable 60,062 20,287
Accrued taxes 121,269 101,314
Accrued interest (4,902) (11,767)
Other current liabilities 16,731 (4,883)
Decrease (increase) in land held 16,388 19,281
Other--net (23,451) 31,266
--------- ---------
Net Cash Flow Provided By Operating Activities 514,695 516,435
--------- ---------
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures (221,904) (229,608)
Capitalized interest (14,261) (14,995)
Other--net (2,362) (6,115)
--------- ---------
Net Cash Flow Used For Investing Activities (238,527) (250,718)
--------- ---------
CASH FLOWS FROM FINANCING ACTIVITIES
Issuance of long-term debt 112,575 112,413
Short-term borrowings--net (15,400) 100,894
Dividends paid on common stock (76,311) (70,745)
Repayment of long-term debt (254,782) (260,536)
Redemption of preferred stock (37,585) (46,511)
Repurchase and retirement of common stock -- (81,251)
Other--net (2,023) 679
--------- ---------
Net Cash Flow Used For Financing Activities (273,526) (245,057)
--------- ---------
Net Cash Flow 2,642 20,660
Cash and Cash Equivalents at Beginning of Period 27,484 26,686
--------- ---------
Cash and Cash Equivalents at End of Period $ 30,126 $ 47,346
========= =========
Supplemental Disclosure of Cash Flow Information:
Cash paid during the period for:
Interest, net of amounts capitalized $ 112,348 $ 128,414
Income taxes $ 81,305 $ 106,440
See Notes to Condensed Consolidated Financial Statements.
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PINNACLE WEST CAPITAL CORPORATION
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
1. The condensed consolidated financial statements include the accounts of
Pinnacle West and its subsidiaries: APS, SunCor and El Dorado. All significant
intercompany balances have been eliminated. Certain prior year balances have
been restated to conform to the current year presentation.
2. In the opinion of the Company, the accompanying unaudited condensed
consolidated financial statements contain all adjustments (consisting of normal
recurring accruals) necessary to present fairly the financial position of
Pinnacle West and its subsidiaries as of September 30, 1998, the results of
operations for the three months, nine months and twelve months ended September
30, 1998 and 1997, and the cash flows for the nine months ended September 30,
1998 and 1997. It is suggested that these condensed consolidated financial
statements and notes to condensed consolidated financial statements be read in
conjunction with the consolidated financial statements and notes to consolidated
financial statements included in the Company's 1997 10-K.
3. The operations of APS are subject to seasonal fluctuations, with variations
in energy usage by customers occurring from season to season and from month to
month within a season, primarily as a result of changing weather conditions. For
this and other reasons, the results of operations for interim periods are not
necessarily indicative of the results to be expected for the full year.
4. See "Liquidity and Capital Resources" in Part I, Item 2 of this report for
changes in capitalization for the nine months ended September 30, 1998.
5. Regulatory Matters --- Electric Industry Restructuring
STATE
The following is a description of regulatory and legislative developments
related to implementation of retail electric competition beginning with the ACC
rules adopted in December 1996 through the proposed settlement agreement in
November 1998.
ACC RULES. In December 1996, the ACC adopted rules that provide a framework for
the introduction of retail electric competition in Arizona. On August 5, 1998,
the ACC adopted amendments to the rules. The ACC rules, as amended, include the
following major provisions:
o The rules apply to virtually all of the Arizona electric utilities
regulated by the ACC, including APS.
o The rules require each affected utility, including APS, to make
available at least 20% of its 1995 system retail peak demand for
competitive generation supply to
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all customer classes beginning January 1, 1999, and 100% beginning
January 1, 2001.
o All affected utility customers with single premise loads of one
megawatt or greater will be eligible for competitive electric services
beginning January 1, 1999, until the 20% level described in the
preceding paragraph is met. Until the 20% level is met, affected
utility customers with single premise loads of forty kilowatts or
greater will be able to aggregate into a combined load of one megawatt
or greater to be eligible for competitive electric services beginning
January 1, 1999.
o Prior to January 1, 2001, residential customers will have access to
competitive services through a quarterly phase-in of one-half percent
of residential customers per quarter beginning January 1, 1999.
o Electric service providers that obtain Certificates of Convenience and
Necessity (CC&Ns) from the ACC will be allowed to supply, market,
and/or broker specified electric services at retail. These services
include electric generation, but exclude electric transmission and
distribution.
o As required by the rules, in February 1998 APS filed with the ACC
proposed tariffs for unbundled service (electric service elements
provided and priced separately). The ACC has not issued a decision in
this matter.
o The rules establish that the ACC shall allow a reasonable opportunity
for the recovery of unmitigated stranded costs. See "Stranded Costs"
below. Affected utilities are expected to take reasonable,
cost-effective steps to mitigate stranded costs.
o Absent a waiver from the ACC, each affected utility must separate
itself from all competitive generation assets and services prior to
January 1, 2001. The separation must be either to an unaffiliated party
or to a separate corporate affiliate or affiliates.
o Beginning January 1, 1999, each affected utility will be prohibited
from providing certain competitive electric services, except through a
separate affiliate.
o The rules contain affiliate transaction rules generally prohibiting an
affected utility and its competitive electric affiliates from sharing
personnel, office space, equipment, services, and systems, except to
the extent appropriate to perform certain permissible shared corporate
support functions. No later than December 31, 1998, each affected
utility must file a compliance plan with the ACC demonstrating its
compliance with the affiliate transaction rules.
In accordance with the rules, on September 15, 1998, APS filed a report
detailing possible mechanisms to provide certain non-rate benefits and a
possible extension of
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the 1996 regulatory agreement to all standard offer customers and a proposed
plan for phase-in implementation of 3,500 residential customers per quarter on a
first come, first served basis.
The amended rules became effective on an emergency basis upon their filing with
the Secretary of State on August 10, 1998. The ACC held hearings on the amended
rules in October 1998 and must complete the process of adopting the amended
rules on a permanent basis within 180 days of the Secretary of State filing. APS
anticipates the completion of this process by year-end 1998 or early 1999.
The Company believes that certain provisions of the 1996 ACC rules and the
amended rules are deficient. In February 1997, a lawsuit was filed by APS to
protect its legal rights regarding the 1996 rules. That lawsuit is pending but
two related cases filed by other utilities have been partially decided in a
manner adverse to those utilities' positions. In October 1998, APS also filed a
lawsuit to protect its legal rights regarding the amended rules.
STRANDED COSTS. In February 1998, the ACC completed a formal, generic hearing on
stranded cost determination and recovery. On June 22, 1998, the ACC issued an
order in this matter. The order allows an affected utility, such as APS, to
choose between two options for the recovery of its stranded costs. Under the
first option, an affected utility that chooses to divest its generating assets
must file a divestiture plan for ACC approval no later than October 1, 1998, and
such divestiture must be completed by January 1, 2001, after which the affected
utility would be permitted to collect 100 percent of its stranded costs,
including a return on the unamortized balance, over a ten-year period. Under the
second option (referred to by the ACC as the "Transition Revenues Methodology"),
an affected utility would be provided sufficient revenues necessary to maintain
financial integrity for a period of ten years or the ACC would "otherwise
provide an allocation of stranded cost responsibilities and risks between
ratepayers and shareholders as is determined to be in the public interest." The
order also states an intent that the various recovery options "will provide the
affected utilities sufficient revenues to enable them to recover appropriate
regulatory assets." In accordance with the order, on August 21, 1998 APS filed
with the ACC the Transition Revenues Methodology as its choice of options for
stranded cost recovery and a related implementation plan relating to its chosen
option. APS does not intend to divest its generating assets except to an
affiliated party. APS believes that certain provisions of the stranded cost
order are deficient and in August 1998 APS filed two lawsuits to protect its
legal rights relating to the order. Based on various assumptions, estimates and
methodologies, APS estimates its recoverable stranded costs (excluding
regulatory assets which have already been addressed in the 1996 regulatory
agreement with the ACC) to be $533 million, assuming a measurement period 1999
through 2004. The Company cannot accurately predict the outcome of this matter.
PROPOSED SETTLEMENT AGREEMENT. On November 4, 1998, APS and the ACC Staff
entered into a proposed settlement agreement related to the implementation of
retail electric competition. In connection with the settlement agreement, APS
and TEP
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entered into a memorandum of understanding for the exchange of certain assets.
The following are the major provisions of each agreement, both of which are
incorporated herein by reference:
PROPOSED SETTLEMENT AGREEMENT WITH ACC STAFF
o APS will reduce its prices by a total of at least 4% in the years 1999
through 2002. Price reductions in 2001 and 2002 will apply only to APS'
residential customers who purchase all their electric services from the
Company.
o There will be a moratorium on filing for retail rate changes before
January 1, 2003, except for the price reductions described above and
certain other limited circumstances.
o In addition to the cost-saving incentive mechanism, the rate filing
moratorium and full recovery of regulatory assets, certain other
aspects of the 1996 regulatory settlement are extended through 2002.
See Note 6 below for additional information on the 1996 regulatory
settlement.
o APS will be permitted to defer for later recovery prudent and
reasonable costs of complying with the amended ACC rules, systems
benefits costs and solar power costs in excess of the levels included
in current rates.
o APS will have the ability to recover stranded costs in exchange for the
divestiture of its 345 kV and 500 kV transmission assets to TEP.
o APS and TEP entered into a memorandum of understanding for the exchange
of certain assets.
o Upon final adoption and approval of the settlement agreement by the
ACC, APS will move to dismiss all of its litigation currently pending
against the ACC.
o APS will establish a separate corporate affiliate for marketing
generation and other competitive electric services before year-end
1998.
o APS will form a separate corporate affiliate and transfer to it
generating assets by year-end 2002.
MEMORANDUM OF UNDERSTANDING WITH TEP
o APS and TEP have entered into a memorandum of understanding to
negotiate in good faith to reach a definitive agreement on the exchange
of certain transmission and generation assets.
o APS would acquire from TEP up to 273 MW of generating capacity in
exchange for APS' 500 kV and 345 kV transmission lines. The assets will
be exchanged at the transmission current book value, which is
approximately $162 million as of
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July, 1998. If TEP is unable to transfer 273 MW of generating
capacity, the deficiency is to be made up by a cash payment from TEP
to APS.
o The transaction is expected to close by December 31, 2000.
o The generating assets are TEP's interest in the Navajo Generating
Station and Four Corners Generating Plant.
A hearing date for the ACC's consideration or approval of the settlement
agreement has not yet been set. The memorandum of understanding provides that a
definitive agreement must be entered into within sixty days of a final order on
the settlement agreement by the ACC.
LEGISLATIVE INITIATIVES. An Arizona joint legislative committee studied electric
utility industry restructuring issues in 1996 and 1997. In conjunction with that
study, Arizona legislative counsel prepared memoranda in late 1997 related to
the legal authority of the ACC to deregulate the Arizona electric utility
industry. The memoranda raise a question as to the degree to which the ACC may,
under the Arizona Constitution, deregulate any portion of the electric utility
industry and allow rates to be determined by market forces. This latter issue
(the ability of the ACC to set rates based on the competitive market) has been
subsequently decided by lower courts in favor of the ACC in two unrelated and
two related lawsuits.
In May 1998, a bill was enacted to facilitate implementation of retail electric
competition in the state. The bill includes the following major provisions: (a)
requirements that Arizona's largest government-operated electric utility (Salt
River Project) and, at their option, smaller city electric systems (i) open
their service territories to electric service providers to implement retail
electric generation competition for 20% of each utility's 1995 retail peak
demand by December 31, 1998 and for all retail customers by December 31, 2000;
(ii) decrease rates by at least 10% over a ten-year period beginning as early as
January 1, 1991; (iii) implement procedures and public processes, including
judicial review at the request of either an interested party or the Arizona
Attorney General, for establishing the terms, conditions and pricing of electric
services as well as certain other decisions affecting retail electric
competition, which procedures and processes are comparable to those already
applicable to public service corporations; (b) a description of the factors
which form the basis of consideration by Salt River Project in determining
stranded costs; and (c) a requirement that metering and meter reading services
be provided on a competitive basis during the first two years of competition
only for customers having demands in excess of one megawatt (and that are
eligible for competitive generation services), and thereafter for all customers
receiving competitive electric generation. In addition, the Arizona legislature
will review and make recommendations for the 1999 legislature on certain
competitive issues.
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FEDERAL
The Energy Policy Act of 1992 and recent rulemakings by FERC have promoted
increased competition in the wholesale electric power markets. The Company does
not expect these rules to have a material impact on its consolidated financial
statements.
Several electric utility reform bills have been introduced during recent
congressional sessions, which as currently written, would allow consumers to
choose their electricity suppliers by 2000 or 2003. These bills, other bills
that are expected to be introduced, and ongoing discussions at the federal level
suggest a wide range of opinion that will need to be narrowed before any
substantial restructuring of the electric utility industry can occur.
REGULATORY ACCOUNTING
APS prepares its financial statements in accordance with the provisions of
Statement of Financial Accounting Standards (SFAS) No. 71, "Accounting for the
Effects of Certain Types of Regulation." SFAS No. 71 requires a cost-based,
rate-regulated enterprise to reflect the impact of regulatory decisions in its
financial statements. APS' existing regulatory orders and current regulatory
environment support its accounting practices related to regulatory assets, which
amounted to approximately $0.9 billion at September 30, 1998. In accordance with
the 1996 regulatory agreement, the ACC accelerated the amortization of
substantially all of APS' regulatory assets to an eight-year period that began
July 1, 1996.
During 1997, the Emerging Issues Task Force (EITF) of the Financial Accounting
Standards Board (FASB) issued EITF 97-4, which requires that SFAS No. 71 be
discontinued no later than when legislation is passed or a rate order is issued
that contains sufficient detail to determine its effect on the portion of the
business being deregulated, which could result in write-downs or write-offs of
physical and/or regulatory assets. Additionally, the EITF determined that
regulatory assets should not be written off if they are to be recovered from a
portion of the entity which continues to apply SFAS No. 71.
Although the ACC has issued rules for transitioning generation services to
competition, there are many unresolved issues. APS continues to apply SFAS No.
71 to all of its operations. If rate recovery of regulatory assets is no longer
probable, whether due to competition or regulatory action, APS would be required
to write off the remaining balance as an extraordinary charge to expense.
GENERAL
Changes in ACC decisions, Arizona and federal legislation, and possible
amendments to the Arizona Constitution may impact the implementation of retail
electric competition in Arizona. Until the details of implementation of
competition, including addressing stranded costs, are determined, the Company
cannot accurately predict the impact of full retail competition on its financial
position, cash flows or results of operation. As
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competition in the electric industry continues to evolve, the Company will
continue to evaluate strategies and alternatives that will position APS to
compete in the new regulatory environment.
6. Regulatory Matters -- 1996 Regulatory Agreement
In April 1996, the ACC approved a regulatory agreement between APS and the ACC
Staff. The major provisions of this agreement are:
o An annual rate reduction of approximately $48.5 million ($29 million
after income taxes), or 3.4% on average for all customers except
certain contract customers, effective July 1, 1996.
o Recovery of substantially all of APS' present regulatory assets through
accelerated amortization over an eight-year period that began July 1,
1996, increasing annual amortization by approximately $120 million ($72
million after income taxes).
o A formula for sharing future cost savings between customers and
shareholders (price reduction formula) referencing a return on equity
(as defined) of 11.25%.
o A moratorium on filing for permanent rate changes prior to July 2,
1999, except under the price reduction formula and under certain other
limited circumstances.
o Infusion of $200 million of common equity into APS by the parent
company, in annual payments of $50 million starting in 1996.
Pursuant to the price reduction formula, in 1997 and in 1998, the ACC approved
retail price decreases of approximately $17.6 million ($10.5 million after
income taxes), or 1.2%, effective July 1, 1997, and approximately $17 million
($10 million after income taxes), or 1.1%, effective July 1, 1998, respectively.
7. Agreement with Salt River Project
On April 25, 1998, APS and Salt River Project entered into a Memorandum of
Agreement in anticipation of, and to facilitate, the opening of the Arizona
electric industry. The Agreement contains the following major components:
o APS and Salt River Project would amend the Territorial Agreement to
remove any barriers to the provision of competitive electricity supply
and non-distribution services.
o APS and Salt River Project would amend the Power Coordination Agreement
to lower the price that APS will pay Salt River Project for purchased
power by approximately $17 million (pretax) in 1999 and by lesser
annual amounts through 2006.
<PAGE>
-15-
o APS and Salt River Project agreed on certain legislative positions
regarding electric utility restructuring at the state and federal
level.
An ACC docket had previously been established and the ACC held a hearing on
August 6, 1998 so that the ACC could review certain provisions of the Memorandum
of Agreement, as amended, including, whether: (a) the Territorial Agreement
remains in the public interest, (b) the Agreement is a contract in restraint of
trade, and (c) the Agreement will materially lessen the potential for retail
electric competition in Arizona.
The Antitrust Unit of the Arizona Attorney General's Office, which has been
involved in the ongoing regulatory and legislative proceedings regarding the
restructuring of the Arizona electric industry, requested clarification of the
operation of certain of the Agreement's provisions. Pursuant to an Addendum to
Memorandum of Agreement, dated as of May 19, 1998 (the "Addendum"), APS and Salt
River Project amended and clarified certain provisions of the Memorandum of
Agreement in response to certain issues raised by the Antitrust Unit. By letter
dated May 19, 1998, the Antitrust Unit advised APS and Salt River Project that,
upon their execution of the Addendum, it would take no action regarding the
language of the Memorandum of Agreement, although it reserved the right to take
action in the future if new information justified doing so.
8. The Palo Verde participants have insurance for public liability payments
resulting from nuclear energy hazards to the full limit of liability under
federal law. This potential liability is covered by primary liability insurance
provided by commercial insurance carriers in the amount of $200 million and the
balance by an industry-wide retrospective assessment program. If losses at any
nuclear power plant covered by the programs exceed the accumulated funds, APS
could be assessed retrospective premium adjustments. The maximum assessment per
reactor under the program for each nuclear incident is approximately $88
million, subject to an annual limit of $10 million per incident. Based upon APS'
29.1% interest in the three Palo Verde units, APS maximum potential assessment
per incident is approximately $77 million, with an annual payment limitation of
approximately $9 million.
The Palo Verde participants maintain "all risk" (including nuclear hazards)
insurance for property damage to, and decontamination of, property at Palo Verde
in the aggregate amount of $2.75 billion, a substantial portion of which must
first be applied to stabilization and decontamination. APS has also secured
insurance against portions of any increased cost of generation or purchased
power and business interruption resulting from a sudden and unforeseen outage of
any of the three units. The insurance coverage discussed in this and the
previous paragraph is subject to certain policy conditions and exclusions.
9. The Financial Accounting Standards Board issued SFAS No. 131 on "Disclosures
about Segments of an Enterprise and Related Information" which is effective for
fiscal years beginning after December 15, 1997. SFAS No. 131 requires that
public companies report
<PAGE>
-16-
certain information about operating segments in their financial statements. It
also establishes related disclosures about products and services, geographic
areas, and major customers. The Company is currently evaluating what impact this
standard will have on its disclosures.
In June 1998 the Financial Accounting Standards Board issued SFAS No. 133
"Accounting for Derivative Instruments and Hedging Activities," which is
effective for the Company in 2000. SFAS No. 133 requires that an entity
recognize all derivatives as either assets or liabilities in the balance sheet
and measure those instruments at fair value. The standard also provides specific
guidance for accounting for derivatives designated as hedging instruments. The
Company is currently evaluating what impact this standard will have on its
consolidated financial statements.
10. In 1997 the Company adopted SFAS No. 128 "Earnings Per Share." This
statement requires the presentation of both basic and diluted earnings per share
on the consolidated financial statements. The following table presents earnings
per average common share outstanding (EPS):
Twelve Months Ended
September 30,
-----------------
Basic EPS: 1998 1997
----- -----
Continuing operations $2.67 $2.44
Discontinued operations - (0.11)
----------------
Net income $2.67 $2.33
================
Diluted EPS:
Continuing operations $2.66 $2.43
Discontinued operations - (0.11)
----------------
Net income $2.66 $2.32
================
Dilutive stock options increased average common shares outstanding by 557,193
and 496,198 for the three-month period ended September 30, 1998 and 1997
respectively; 567,006 and 482,082 for the nine-month period ended September 30,
1998 and 1997 respectively; and 450,228 and 482,179 for the twelve-month period
ended September 30, 1998 and 1997 respectively, but had no effect on net income.
Total average common shares outstanding for the purposes of calculating diluted
earnings per share were 85,326,808 and 85,244,147 for the three-month period
ended September 30, 1998 and 1997 respectively; 85,355,520 and 86,246,399 for
the nine-month period ended September 30, 1998 and 1997 respectively; and
85,223,290 and 86,672,761 for the twelve-month period ended September 30, 1998
and 1997 respectively.
<PAGE>
-17-
PINNACLE WEST CAPITAL CORPORATION
Item 2. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS
OF OPERATIONS.
OPERATING RESULTS
The following table shows the income and/or loss of Pinnacle West and its
subsidiaries for the three-month, nine-month and twelve-month periods ended
September 30, 1998 and 1997:
<TABLE>
<CAPTION>
Income (Loss)
(Unaudited)
(Thousands of Dollars)
Three Months Ended Nine Months Ended Twelve Months Ended
September 30, September 30, September 30,
1998 1997 1998 1997 1998 1997
------- ------- ------- ------- ------- -------
<S> <C> <C> <C> <C> <C> <C>
APS $130,846 $126,715 $209,652 $218,032 $230,310 $212,837
SunCor (1,419) 451 3,866 2,706 6,494 5,674
El Dorado 188 63 4,395 7,019 5,566 7,660
Pinnacle West (1) (2,334) (2,889) (10,549) (10,853) (16,054) (25,466)
-------- -------- -------- -------- -------- --------
Net Income $127,281 $124,340 $207,364 $216,904 $226,316 $200,705
======== ======== ======== ======== ======== ========
</TABLE>
(1) Includes Pinnacle West's interest expense, discontinued operations and
operating expenses net of income tax benefits/(expenses). Income tax benefits
(expenses) are as follows (in thousands): $907 and $1,264 for the three months
ended September 30, 1998 and 1997, respectively; $(553) and $2,472 for the nine
months ended September 30, 1998 and 1997, respectively; and $(275) and $8,945
for the twelve months ended September 30, 1998 and 1997, respectively.
APS
OPERATING RESULTS - THREE-MONTH PERIOD ENDED SEPTEMBER 30, 1998
COMPARED WITH THREE-MONTH PERIOD ENDED SEPTEMBER 30, 1997
Earnings increased $4 million in the three-month comparison primarily
because of customer growth, weather effects, and higher profitability from power
marketing activities, partially offset by higher fuel expenses and a retail
price reduction. See Note 6 of Notes to Condensed Consolidated Financial
Statements for information on the price reduction.
<PAGE>
-18-
Operating revenues increased $108 million because of increased power
marketing revenues ($71 million), customer growth ($28 million), and weather
effects ($18 million), partially offset by the price reduction ($6 million) and
other ($3 million). The increase in power marketing revenues was a result of
higher market prices and increased activity. The increase in power marketing
revenues was accompanied by related increases in purchased power.
Fuel expenses increased $94 million primarily because of higher
purchased power prices, increased wholesale and retail sales volumes, and the
effects of two fuel-related settlements in the third quarter of 1997. The
settlements contributed approximately $21 million to 1997 pretax earnings and
are reflected on the income statement as reductions in fuel expense and as other
income.
OPERATING RESULTS - NINE-MONTH PERIOD ENDED SEPTEMBER 30, 1998 COMPARED
WITH NINE-MONTH PERIOD ENDED SEPTEMBER 30, 1997
Earnings decreased $8 million in the nine-month comparison primarily
because of two fuel-related settlements recorded in 1997, increased operations
and maintenance expenses, the effects of weather, and two retail price
reductions, partially offset by customer growth and higher profitability from
power marketing activities. See Note 6 of Notes to Condensed Consolidated
Financial Statements for additional information about the price reduction.
The two fuel-related settlements increased 1997 pretax earnings by
approximately $21 million. These settlements are reflected on the income
statement as reductions in fuel expense and as other income.
Operations and maintenance expenses increased $22 million related to
impending competition and growth, outages at power plants and other
miscellaneous factors.
Operating revenues increased $92 million because of increased power
marketing revenues ($69 million) and customer growth ($58 million). These
factors were partially offset by the effects of weather ($20 million) and the
price reductions ($15 million). The increase in power marketing revenues was a
result of higher prices and increased activity. The increase in power marketing
revenues was accompanied by related increases in purchased power.
OPERATING RESULTS - TWELVE-MONTH PERIOD ENDED SEPTEMBER 30, 1998
COMPARED WITH TWELVE-MONTH PERIOD ENDED SEPTEMBER 30, 1997
Earnings increased $17 million in the twelve-month comparison primarily
because of customer growth and higher profitability from power marketing
activities. These positive factors more than offset two retail price reductions
and the effects of weather. See Note 6 of Notes to Condensed Consolidated
Financial Statements for
<PAGE>
-19-
additional information about the price reductions. The period ended September
30, 1997 also benefited from two fuel-related settlements and the recognition of
$8 million of income tax benefits associated with capital loss carryforwards.
Operating revenues increased $121 million because of increased power
marketing revenues ($85 million) and customer growth ($69 million), partially
offset by the price reductions ($18 million), the effects of weather ($10
million), and other ($5 million). The increase in power marketing revenues was a
result of higher prices and increased activity. The increase in power marketing
revenues was accompanied by related increases in purchased power.
The two fuel-related settlements increased 1997 pretax earnings by
approximately $21 million. These settlements are reflected on the income
statement as reductions in fuel expense and as other income.
Operations and maintenance expenses decreased $8 million because of a
$32 million pretax charge for a voluntary severance program recorded in 1996 and
related savings in 1997, partially offset by higher expenses related to
impending competition and growth, outages at power plants and other
miscellaneous factors.
NON-UTILITY OPERATIONS
The parent company's losses decreased in the third quarter and
nine-month period because of lower interest expense resulting from debt
reduction. The twelve-month period ended September 30, 1997 includes a loss from
discontinued operations on a legal matter related to MeraBank, A Federal Savings
Bank (a former subsidiary).
SunCor's earnings were lower in the three-month period which is
attributed to a decrease in net land and home sales. SunCor's earnings increased
in the nine-month and twelve-month periods ended September 30, 1998 because of
an increase in net land sales.
El Dorado's decreased earnings in the nine-month and twelve-month
periods were the result of investment sales in 1997.
INVESTMENT TAX CREDIT AMORTIZATION
As part of a 1994 rate settlement with the ACC, APS accelerated
amortization of substantially all deferred ITCs over a five-year period that
ends on December 31, 1999. The amortization of ITCs decreases annual
consolidated income tax expense by approximately $24 million.
<PAGE>
-20-
LIQUIDITY AND CAPITAL RESOURCES
PARENT COMPANY
The parent company's cash requirements and its ability to fund those
requirements are discussed under "Capital Needs and Resources" in Management's
Discussion and Analysis of Financial Condition and Results of Operation in Part
II, Item 7 of the 1997 10-K.
During the nine-months ended September 30, 1998, the parent company
redeemed approximately $86 million of its long-term debt with cash from
operations and short-term borrowings.
As a result of the 1996 regulatory agreement (see Note 6 of Notes to
Condensed Consolidated Financial Statements in Part I, Item 1 of this report),
the parent company has invested $50 million in APS in 1996 and 1997 and will
invest similar amounts annually in 1998 and 1999.
The Board declared a quarterly dividend of 32.5 cents per share of
common stock, payable December 1, 1998 to shareholders of record on November 2,
1998, totaling approximately $27.5 million.
APS
For the nine months ended September 30, 1998, APS incurred
approximately $221 million in capital expenditures, which is approximately 68%
of the most recently estimated 1998 capital expenditures. APS projected capital
expenditures for the next three years are: 1998, $323 million; 1999, $322
million; and 2000, $317 million, respectively. These amounts include about $30 -
$35 million each year for nuclear fuel expenditures. In addition, APS is
considering expanding certain of its businesses over the next several years,
which may result in increased expenditures.
APS' long-term debt and preferred stock redemption requirements and
payment obligations on a capitalized lease for the next three years are: 1998,
$221 million; 1999, $174 million; and 2000, $104 million. During the nine months
ended September 30, 1998, APS redeemed approximately $142 million of its
long-term debt and approximately $38 million of its preferred stock with cash
from operations and long-term and short-term debt. On December 1, 1998 APS will
redeem all $37.5 million of its $1.8125 Cumulative Preferred Stock, Series W. As
a result of the 1996 regulatory agreement (see Note 6 of Notes to Condensed
Consolidated Financial Statements), the Company invested $50 million in APS in
1996 and 1997 and will invest similar amounts annually in 1998 and 1999.
<PAGE>
-21-
Although provisions in APS' bond indenture, articles of incorporation,
and financing orders from the ACC establish maximum amounts of additional first
mortgage bonds and preferred stock that APS may issue, management does not
expect any of these restrictions to limit APS' ability to meet its capital
requirements.
YEAR 2000 READINESS DISCLOSURE
As the year 2000 approaches many companies face problems because many
software application and operational programs will not properly recognize
calendar dates beginning with the year 2000. The Company and its subsidiaries
are addressing the Year 2000 issue as described below. APS initiated a
comprehensive company-wide Year 2000 program over a year ago to review and
resolve all Year 2000 issues in critical systems and equipment in a timely
manner in an effort to ensure the reliability of electric service to its
customers. This included a company-wide awareness program of the Year 2000
issue.
APS has been actively implementing and replacing new systems and
technology since 1995 for reasons unrelated to the year 2000, and these actions
have resulted in substantially all of its major information technology (IT)
systems becoming Year 2000 compliant. The Company, APS, SunCor and El Dorado
have made, and will continue to make, certain modifications to its computer
hardware and software systems and applications, including IT and non-IT systems,
in an effort to ensure they are capable of handling changing business needs,
including dates in the year 2000 and thereafter. In addition, other APS IT
systems and non-IT systems, including embedded technology and real-time process
control systems, are being analyzed for potential modifications.
To date, the Company, APS and El Dorado have inventoried and assessed
essentially all critical IT and non-IT systems and any renovation, validation
and implementation of these systems will be completed by mid-1999 for all
critical systems that effect operations, except for those items that can only be
completed during maintenance outages at Palo Verde, which will be completed for
the last unit during the last half of 1999. APS has also designated an internal
audit/quality review team that is periodically reviewing the individual Year
2000 projects and their Year 2000 readiness. SunCor is in the process of
inventorying and assessing its IT and non-IT systems, and it expects this
analysis to be completed by year-end 1998 and remediation and testing to be
completed by mid-1999. The cost to the Company of Year 2000 remediation has not
had, and is not expected to have, a material adverse effect on the Company's
financial position, cash flows, or results of operations.
The Company, APS, SunCor and El Dorado are communicating with their
significant suppliers, business partners, other utilities and large customers to
determine the extent to which they may be affected by these third parties' plans
to remediate their own Year 2000 issues in a timely manner. The Company, APS,
SunCor and El Dorado have been interfacing with suppliers of systems, services
and materials in order to assess whether their schedules for analysis and
remediation of Year 2000 issues are
<PAGE>
-22-
timely and to assess their ability to continue to supply required services and
materials. APS is also working with the North American Electric Reliability
Council (NERC) through the Western Systems Coordinating Council (WSCC) to
develop operational plans for stable grid operation that will be utilized by the
Company and other utilities in the western United States. However, the Company
cannot currently predict the effect on the Company if the systems of these other
companies are not Year 2000 compliant.
APS currently estimates that it will spend approximately $5 million
relating to Year 2000 issues, about half of which has been spent to date. This
does not include expenditures incurred since 1995 to implement and replace
systems for reasons unrelated to the Year 2000, as discussed above. Costs
incurred to address the Year 2000 issue are charged to operating expenses as
incurred and are expected to be funded by available cash balances and cash
provided by operations.
The Company currently expects that its most reasonably likely worst case
Year 2000 scenario would be intermittent loss of power to APS customers, similar
to an outage during a severe weather disturbance. In this situation APS would
restore power as soon as possible by, among other things, re-routing power
flows. The Company does not currently expect that this scenario would have a
material effect on its financial position, cash flows or results of operations.
The Company is working to develop its own contingency plans to handle
Year 2000 issues, and expects these plans to be completed by mid-1999. As
discussed above, APS is also working with NERC and WSCC to develop contingency
plans related to grid operation.
COMPETITION AND ELECTRIC INDUSTRY RESTRUCTURING
See Note 5 of Notes to Condensed Consolidated Financial Statements in
Part I, Item 1 of this report for discussions of competitive developments and
regulatory accounting. See Note 7 of Notes to Condensed Consolidated Financial
Statements in Part I, Item 1 of this report for a discussion of a proposed
amendment to a Power Coordination Agreement with Salt River Project that APS
estimates would reduce its pretax costs for purchased power by approximately $17
million in 1999 and by lesser annual amounts through 2006.
<PAGE>
-23-
RATE MATTERS
See Note 6 of Notes to Condensed Consolidated Financial Statements in
Part I, Item 1 of this report for a discussion of a price reduction, which
became effective on July 1, 1998.
FORWARD-LOOKING STATEMENTS
The above discussion contains forward-looking statements that involve
risks and uncertainties. Words such as "estimates," "expects," "anticipates,"
"plans," "believes," "projects," and similar expressions identify
forward-looking statements. These risks and uncertainties include, but are not
limited to, the ongoing restructuring of the electric industry; the outcome of
the regulatory proceedings relating to the restructuring; regulatory, tax and
environmental legislation; the ability of APS to successfully compete outside
its traditional regulated markets; regional economic conditions, which could
affect customer growth; the cost of debt and equity capital; weather variations
affecting customer usage; technological developments in the electric industry;
the strength of the real estate market; and Year 2000 issues.
These factors and the other matters discussed above may cause future
results to differ materially from historical results, or from results or
outcomes currently expected or sought by the Company.
<PAGE>
-24-
PART II - OTHER INFORMATION
CONSTRUCTION AND FINANCING PROGRAMS
See "Liquidity and Capital Resources" in Part I, Item 2 of this report
for a discussion of the Company's construction and financing programs.
COMPETITION AND ELECTRIC INDUSTRY RESTRUCTURING
See Note 5 of Notes to Condensed Consolidated Financial Statements in
Part I, Item 1 of this report for a discussion of competition and the rules
regarding the introduction of retail electric competition in Arizona. On
February 28, 1997 and October 16, 1998, lawsuits were filed by APS to protect
its legal rights regarding the rules and the amended rules, respectively, and in
each complaint APS asked the Court for (i) a judgment vacating the retail
electric competition rules, (ii) a declaratory judgment that the rules are
unlawful because, among other things, they were entered into without proper
legal authorization, and (iii) a permanent injunction barring the ACC from
enforcing or implementing the rules and from promulgating any other regulations
without lawful authority. ARIZONA PUBLIC SERVICE COMPANY v. ARIZONA CORPORATION
COMMISSION, CV 97-03753 (consolidated under CV 97-03748.) ARIZONA PUBLIC SERVICE
COMPANY v. ARIZONA CORPORATION COMMISSION, CV 98-18896. On August 28, 1998, the
Company filed two lawsuits to protect its legal rights under the stranded cost
order and in its complaints the Company asked the Court to vacate and set aside
the order. ARIZONA PUBLIC SERVICE COMPANY v. ARIZONA CORPORATION COMMISSION, CV
98-15728. ARIZONA PUBLIC SERVICE COMPANY v. ARIZONA CORPORATION COMMISSION,
1-CA-CC-98-0008. See "State-Proposed Settlement Agreement" in Note 5 of Notes to
Condensed Consolidated Financial Statements in Part I, Item 1 of this Report
regarding the possible dismissal of the lawsuits described in this paragraph.
ITEM 6. EXHIBITS AND REPORTS ON FORM 8-K
(a) Exhibits
EXHIBIT NO. DESCRIPTION
- ----------- -----------
27.1 Financial Data Schedule
In addition to those Exhibits shown above, the Company hereby
incorporates the following Exhibits pursuant to Exchange Act Rule 12b-32 and
Regulation ss.229.10(d) by reference to the filings set forth below:
<PAGE>
-25-
<TABLE>
<CAPTION>
EXHIBIT NO. DESCRIPTION ORIGINALLY FILED AS EXHIBIT: FILE NO.(a) DATE EFFECTIVE
- ----------- ----------- ---------------------------- ----------- --------------
<S> <C> <C> <C> <C>
10.1 Articles of Incorporation 19.1 to the Company's 1-8962 11-14-88
restated as of July 29, 1988 September 30, 1988
Form 10-Q Report
10.2 Bylaws, amended as of 3.1 to the Company's 1995 1-8962 4-1-96
February 21, 1996 Form 10-K Report
10.3 Settlement Agreement 99.1 to APS' September 30, 1-4473 11-16-98
between APS and the ACC 1998 Form 10-Q Report
dated November 4, 1998,
which includes a Memorandum
of Understanding with TEP
</TABLE>
(b) Reports on Form 8-K
During the quarter ended September 30, 1998, and the period from
October 1 through November 13, 1998, the Company filed the following reports on
Form 8-K:
Report dated August 5, 1998 regarding the ACC rules related to retail
competition.
- --------
(a) Reports filed under File No. 1-4473 were filed in the office of the
Securities and Exchange Commission located in Washington, D.C.
<PAGE>
SIGNATURES
----------
Pursuant to the requirements of the Securities Exchange Act of 1934,
the Company has duly caused this report to be signed on its behalf by the
undersigned thereunto duly authorized.
PINNACLE WEST CAPITAL CORPORATION
(Registrant)
Dated: November 13, 1998 By: George A. Schreiber, Jr.
---------------------------------
George A. Schreiber, Jr.
Executive Vice President and
Chief Financial Officer
(Principal Financial Officer
and Officer Duly Authorized
to sign this Report)
<TABLE> <S> <C>
<ARTICLE> UT
<MULTIPLIER> 1,000
<CURRENCY> U.S. DOLLARS
<S> <C>
<PERIOD-TYPE> 9-MOS
<FISCAL-YEAR-END> DEC-31-1998
<PERIOD-START> JAN-01-1998
<PERIOD-END> SEP-30-1998
<EXCHANGE-RATE> 1
<BOOK-VALUE> PER-BOOK
<TOTAL-NET-UTILITY-PLANT> 4,687,675
<OTHER-PROPERTY-AND-INVEST> 582,280
<TOTAL-CURRENT-ASSETS> 571,615
<TOTAL-DEFERRED-CHARGES> 1,069,942
<OTHER-ASSETS> 0
<TOTAL-ASSETS> 6,911,512
<COMMON> 1,552,128
<CAPITAL-SURPLUS-PAID-IN> 0
<RETAINED-EARNINGS> 604,718
<TOTAL-COMMON-STOCKHOLDERS-EQ> 2,156,846
9,401
123,795
<LONG-TERM-DEBT-NET> 2,054,473
<SHORT-TERM-NOTES> 0
<LONG-TERM-NOTES-PAYABLE> 0
<COMMERCIAL-PAPER-OBLIGATIONS> 115,350
<LONG-TERM-DEBT-CURRENT-PORT> 158,077
0
<CAPITAL-LEASE-OBLIGATIONS> 0
<LEASES-CURRENT> 0
<OTHER-ITEMS-CAPITAL-AND-LIAB> 2,293,570
<TOT-CAPITALIZATION-AND-LIAB> 6,911,512
<GROSS-OPERATING-REVENUE> 1,644,225
<INCOME-TAX-EXPENSE> 140,148
<OTHER-OPERATING-EXPENSES> 756,744
<TOTAL-OPERATING-EXPENSES> 1,178,945
<OPERATING-INCOME-LOSS> 465,280
<OTHER-INCOME-NET> (117,768)
<INCOME-BEFORE-INTEREST-EXPEN> 0
<TOTAL-INTEREST-EXPENSE> 113,148
<NET-INCOME> 207,364
0
<EARNINGS-AVAILABLE-FOR-COMM> 207,364
<COMMON-STOCK-DIVIDENDS> 76,311
<TOTAL-INTEREST-ON-BONDS> 87,558
<CASH-FLOW-OPERATIONS> 514,695
<EPS-PRIMARY> 2.45
<EPS-DILUTED> 2.43
</TABLE>
