ITEM 1. BUSINESS
THE COMPANY
Pinnacle West Capital Corporation (the "Company") was incorporated in 1985 under the laws of the State of Arizona and is engaged in the acquisition and holding of securities of corporations for investment purposes. The principal executive offices of the Company are located at 400 East Van Buren Street, Phoenix, Arizona 85004 (telephone 602-379-2500).
The Company and its subsidiaries employ approximately 7,915 persons. Of these employees, approximately 7,050 are employees of the Company's principal subsidiary, Arizona Public Service Company ("APS"), and employees assigned to joint projects of APS where APS serves as a project manager, and approximately 865 are employees of the Company and its other subsidiaries.
Other subsidiaries of the Company, in addition to APS, include SunCor Development Company ("SunCor") and El Dorado Investment Company ("El Dorado"). SunCor is engaged primarily in the owning, holding and development of real property. El Dorado is involved in the business of making equity investments in other companies. See "Business of Non-Utility Subsidiaries" in this Item for further information regarding SunCor and El Dorado.
Effective December 16, 1986, the Company acquired MeraBank, A Federal Savings Bank ("MeraBank"). On January 31, 1990, MeraBank was placed in receivership, and is therefore considered a discontinued operation of the Company for financial reporting purposes. See Note 2 of the Notes to the Consolidated Financial Statements in Item 8 for information regarding the Company's $450 million cash infusion into MeraBank in settlement of claims made by certain federal agencies with respect to MeraBank.
CAPITAL REQUIREMENTS. During the past three years, the Company's primary cash needs were for the repayment of principal and interest on its outstanding debt. Additional cash needs in 1993 were related to the fourth quarter restoration of common stock dividends.
As a result of a restructuring of substantially all of its outstanding debt in 1990, and the prepayment of approximately $112 million, $96 million and $152 million of its long-term debt in 1991, 1992 and 1993, respectively, the Company has reduced required principal debt payments for the next three years. The Company's principal and interest payment obligations during 1994, 1995 and 1996 are expected to total approximately $129 million, $129 million and $83 million, respectively (based upon certain anticipated prepayments). See Note 6 of the Notes to the Company's Consolidated Financial Statements in Item 8 for additional information regarding the Company's and APS' outstanding long-term debt.
The Company's ability to satisfy its debt service obligations is substantially dependent upon the receipt of common stock dividends from APS. The Company has in place a $40 million liquidity facility to assist the Company in meeting its debt service requirements in the event that cash flow is less than anticipated. The facility is available for principal and interest payments on the Company's outstanding debt, with a maximum of $20 million for principal payments.
The terms and provisions of certain of the Company's financing agreements place severe restrictions on the Company's ability to incur additional debt, to make capital infusions into its subsidiaries (excluding APS), to make other new investments and to pay cash dividends to its shareholders unless certain conditions are met. While the debt under these financing agreements remains outstanding, the Company has agreed not to incur new debt, except generally (and with certain restrictions) for (1) borrowings to reduce, refinance or prepay existing debt and (2) borrowings under the liquidity facility discussed in the immediately preceding paragraph. The Company's ability to pay cash dividends or to make other corporate distributions is dependent upon the satisfaction of certain financial covenants. The Company restored a dividend on its common stock in the fourth quarter of 1993.
In the event of a sale of all or substantially all of the assets or shares of common stock of El Dorado or SunCor, the net cash proceeds must be applied by the Company to reduce its outstanding debt. Until the Company's lenders are fully repaid, (1) any new investments by the Company in its subsidiaries (excluding APS) are generally restricted to $15 million in the aggregate and (2) any other new investments by the Company are generally restricted to $20 million in the aggregate. As of December 31, 1993, the Company had not made any such investments.
As part of the Company's 1990 debt restructuring, the Company granted substantially all of its lenders a security interest in the outstanding common stock of APS pursuant to a Pledge Agreement, dated as of January 31, 1990 (the "Pledge Agreement"). At December 31, 1993, the APS common stock secured approximately $564 million of the Company's outstanding debt. Any borrowings under the Company's liquidity facility (see above) would also be secured by the APS common stock owned by the Company. Until the Company and the collateral agent under the Pledge Agreement (the "Collateral Agent") receive notice of the occurrence and continuation of an Event of Default (as defined in the Pledge Agreement), the Company is entitled to exercise or refrain from exercising any and all voting and other consensual rights pertaining to the APS common stock. As to matters other than the election of directors, the Company agreed not to exercise or refrain from exercising any such rights if, in the Collateral Agent's judgment, such action would have a material adverse effect on the value of the APS common stock. After notice of an Event of Default, the Collateral Agent would have the right to vote the APS common stock.
REGULATION
PUBLIC UTILITY HOLDING COMPANY
The Company currently conducts no significant business activities other than investing in its subsidiaries and owns no significant assets other than the common stock of its subsidiaries. The Company and its subsidiaries are currently exempt from registration under the Public Utility Holding Company Act of 1935 (the "Holding Company Act"); however, there are limits on the extent to which the Company can diversify beyond energy-related fields without affecting its exempt status. In February 1989, the Securities and Exchange Commission (the "SEC") released for public comment a proposed rule under the Holding Company Act relating to holding companies, like the Company, that are exempt under Section 3(a)(1) of the Holding Company Act. The proposed rule, if finally adopted by the SEC in its present form, could require the divestiture of a portion of the Company's interests in non-utility businesses within a three-year period after the rule's adoption in order for the Company to maintain its Section 3(a)(1) exemption. If the Company failed to maintain this exemption, the proposed rule would require the Company to divest itself of all of its interests in non-utility businesses within the same three-year period. At this time, the Company is unable to predict whether the proposed rule will be adopted by the SEC and, if so, in what form it will be adopted.
On May 1, 1990, the ACC approved the filing of a petition with the SEC requesting the SEC to revoke or modify the Company's exemption under the Holding Company Act. The SEC has the power to terminate the Company's exemption upon thirty days notice to the Company if it determines that a question exists as to whether the exemption may be detrimental to the public interest or the interests of investors or consumers. In the event of the exercise of such power by the SEC, if the Company were to file an application with the SEC during such thirty-day period requesting an exemption order, the Company's exemption would remain in place until the SEC ruled on such application. If the Company ultimately were to have its exemption modified, conditioned or revoked, APS could be subject to SEC regulation in many aspects of its business, including those relating to securities issuances, diversification and transactions among affiliates. In a series of responses to the ACC's petition and subsequent ACC letters to the SEC, the Company has asked the SEC to refuse to take the action requested by the ACC. The Company cannot predict what action, if any, the SEC may take with respect to the ACC petition.
ARIZONA CORPORATION COMMISSION REPORTING REQUIREMENTS
On April 29, 1985, the ACC issued an order subjecting the Company and APS to certain reporting requirements in connection with certain of their activities. The order requires the Company to report to the ACC on a monthly basis concerning the Company's diversification activities and plans, financing arrangements and changes in management. The order also requires monthly reports describing transactions between APS and the Company or its affiliates.
ARIZONA CORPORATION COMMISSION AFFILIATED INTEREST RULES
On March 14, 1990 the ACC issued an order adopting certain rules purportedly applicable only to a certain class of public utilities regulated by the ACC, including APS. The rules define the terms "public utility holding company" and "affiliate" with respect to public service corporations regulated by the ACC in such a manner as to include the Company and all of the Company's non-public service corporation subsidiaries. By their terms, the rules, among other things, require public utilities, such as APS, to receive ACC approval prior to (1) obtaining an interest in, or guaranteeing or assuming the liabilities of, any affiliate not regulated by the ACC; (2) lending to any such affiliate (except for short-term loans in an amount less than $100,000); or (3) using utility funds to form a subsidiary or divest itself of any established subsidiary. The rules also would prevent a utility from transacting business with an affiliate unless the affiliate agrees to provide the ACC "access to the books and records of the affiliate to the degree required to fully audit, examine or otherwise investigate transactions between the public utility and the affiliate." In addition, the rules provide that an "affiliate or holding company may not divest itself of, or otherwise relinquish control of, a public utility without thirty (30) days prior written notification to the [ACC]" and would require all public utilities subject to them and all public utility holding companies to annually "provide the [ACC] with a description of diversification plans for the current calendar year that have been approved by the Boards of Directors." The order became effective as to APS on December 1, 1992. The rules have not had, nor does the Company expect the rules to have, a material adverse impact on the business or operations of the Company.
BUSINESS OF ARIZONA PUBLIC SERVICE COMPANY
Following is a discussion of the business of APS, the Company's principal subsidiary.
GENERAL
APS was incorporated in 1920 under the laws of Arizona and is engaged principally in serving electricity in the State of Arizona. The principal executive offices of APS are located at 400 North Fifth Street, Phoenix, Arizona 85004 (telephone 602-250-1000). APS currently employs approximately 7,050 persons, which includes employees assigned to joint projects where APS is project manager.
APS serves approximately 654,000 customers in an area that includes all or part of 11 of Arizona's 15 counties. During 1993, no single purchaser or user of energy accounted for more than 3% of total electric revenues.
INDUSTRY AND COMPANY ISSUES
The utility industry continues to experience a number of challenges. Depending on the circumstances of a particular utility, these may include (i) competition in general from numerous sources; (ii) effects of the National Energy Policy Act of 1992 (the "Energy Act"); (iii) difficulties in meeting government imposed environmental requirements; (iv) the necessity to make substantial capital outlays for transmission and distribution facilities; (v) uncertainty regarding projected electrical demand growth; (vi) controversies over electromagnetic fields; (vii) controversies over the safety and use of nuclear power; (viii) issues related to spent fuel and low level waste (see "Generating Fuel" below); and (ix) increasing costs of wages and materials.
The impact on APS of other utility industry problems is discussed in this Item under "Environmental Matters." Also see "Water Supply" in this Item with respect to certain problems specific to APS and other utilities.
COMPETITION
Certain territory adjacent to or within areas served by APS is served by other investor-owned utilities (notably Tucson Electric Power Company serving electricity in the Tucson area, Southwest Gas Corporation serving gas throughout the state, and Citizens Utilities Company serving electricity and gas in various locations throughout the state) and a number of cooperatives, municipalities, electrical districts, and similar types of governmental organizations (principally the Salt River Project Agricultural Improvement and Power District ("SRP") serving electricity in various areas in and around Phoenix).
APS expects increased competition in the future, mostly with respect to large customers, from entities offering alternative sources of energy. In recent years, changing laws and governmental regulations, interest in self- generation, competition from nonregulated energy suppliers, and aggressive marketing from the gas industry, are providing some utility customers with alternative sources to satisfy their energy needs. This may be increased as a result of the Energy Act which, among other things, removes certain previously existing barriers to entry into electric generation. The Energy Act also permits certain other parties to compete for resale customers currently served by a particular utility and to use that utility's transmission facilities in order to do so. The requirements with respect to implementation of the Energy Act have not yet been completely determined, so APS cannot currently predict its impact on APS' business and operations.
In order to remain competitive in this changing environment, APS has determined that it must be a cost-effective supplier, provide excellent service and be knowledgeable about its customers' businesses. APS is concentrating on several areas which are key to the success of this strategy, including effectively managing its operating and maintenance expenses; reinforcing the importance of customer needs among APS employees; and working with customers to evaluate, recommend and provide services which will optimize their efficiency.
CAPITAL STRUCTURE
The capital structure of APS (which, for this purpose, includes short-term borrowings and current maturities of long-term debt) as of December 31, 1993 is tabulated below.
Amount Percentage ---------- ---------- (Thousands of Dollars) Long-Term Debt Less Current Maturities: First mortgage bonds................................ $1,729,070 Other............................................... 395,584 ---------- Total long-term debt less current maturities...... 2,124,654 50.7% ---------- Non-Redeemable Preferred Stock........................ 193,561 4.6 ---------- Redeemable Preferred Stock............................ 197,610 4.7 ---------- Common Stock Equity: Common stock, $2.50 par value, 100,000,000 shares authorized; 71,264,947 shares outstanding......... 178,162 Premiums and expenses............................... 1,037,681 Retained earnings................................... 307,098 ---------- Total common stock equity......................... 1,522,941 36.4 ---------- Total capitalization............................ 4,038,766 Current Maturities of Long-Term Debt.................. 3,179 .1 Short-Term Borrowings................................. 148,000 3.5 ---------- --------
Total........................................... $4,189,945 100.0% ========== ========
See Notes 6, 7, and 8 of Notes to the Consolidated Financial Statements in Item 8.
On March 1, 1994 APS redeemed all of the outstanding shares of its $8.80 Cumulative Preferred Stock, Series K ($100 par value), in the amount of $14.21 million. On March 2, 1994, APS issued $100 million of its First Mortgage Bonds, 6 5/8% Series due 2004 and applied the net proceeds to the repayment of short-term debt that had been incurred for the redemption of preferred stock and for general corporate purposes.
So long as any of APS' first mortgage bonds are outstanding, APS is required for each calendar year to deposit with the trustee under its mortgage cash in a formularized amount related to net additions to APS' mortgaged utility plant; however, APS may satisfy all or any part of this "replacement fund" requirement by utilizing redeemed or retired bonds, net property additions, or property retirements. For 1993, the replacement fund requirement amounted to approximately $122 million. Many, though not all, of the bonds issued by APS under its mortgage are redeemable at their par value plus accrued interest with cash deposited by APS in the replacement fund, subject in many cases to a period of time after the original issuance of the bonds during which they may not be so redeemed and/or to other restrictions on any such redemption. The cash deposited with the trustee by APS in partial satisfaction of its 1993 replacement fund requirements will be used to redeem $60.264 million in aggregate principal amount of APS' First Mortgage Bonds, 10 3/4% Series due 2019, at their principal amount plus accrued interest, on April 4, 1994.
RATES
STATE. The ACC has regulatory authority over APS in matters relating to retail electric rates and the issuance of securities. See "Rate Case Settlement" in Note 3 of the Notes to the Consolidated Financial Statements in Item 8 for a discussion of the December 1991 settlement of APS' most recent retail rate case before the ACC.
FEDERAL. APS' rates for wholesale power sales and transmission services are subject to regulation by the Federal Energy Regulatory Commission ("FERC"). During 1993, approximately 8% of APS' electric operating revenues resulted from such sales and charges. For most wholesale transactions regulated by the FERC, a fuel adjustment clause results in monthly adjustments for changes in the actual cost of fuel for generation and in the fuel component of purchased power expense.
CONSTRUCTION PROGRAM
Although its plans are subject to change, APS does not presently intend to construct any new major baseload generating units for at least the next ten years. Utility construction expenditures for the years 1994 through 1996 are therefore expected to be primarily for expanding transmission and distribution capabilities to meet customer growth, upgrading existing facilities, and for environmental purposes. Construction expenditures, including expenditures for environmental control facilities, for the years 1994 through 1996 have been estimated as follows:
(MILLIONS OF DOLLARS) BY YEAR BY MAJOR FACILITIES - ------------------------------ ------------------------------------------ 1994 $279 Electric generation $271 1995 302 Electric transmission 92 1996 293 Electric distribution 390 ---- General facilities 121 $874 ---- ==== $874 ====
The amounts for 1994 through 1996 include expenditures for nuclear fuel but exclude capitalized interest costs and capitalized property taxes. APS conducts a continuing review of its construction program. This program and the above estimates are subject to periodic revisions based upon changes in assumptions as to system reliability, system load growth, rates of inflation, the availability and timing of environmental and other regulatory approvals, the availability and costs of outside sources of capital, and changes in project construction schedules. During the years 1991 through 1993, APS incurred approximately $641 million in construction expenditures and approximately $31 million in additional capitalized items.
ENVIRONMENTAL MATTERS
Pursuant to the Clean Air Act, the United States Environmental Protection Agency ("EPA") has adopted regulations, applicable to certain federally- protected areas, that address visibility impairment that can be reasonably attributed to specific sources. In September 1991, the EPA issued a final rule that would limit sulfur dioxide emissions at the Navajo Generating Station ("NGS"). Compliance with the emission limitation becomes applicable to NGS Units 1, 2, and 3 in 1997, 1998, and 1999, respectively. SRP, the NGS operating agent, has estimated a capital cost of $530 million, most of which will be incurred from 1995-1998, and annual operations and maintenance costs of approximately $10 million per unit, for NGS to meet these requirements. APS will be required to fund 14% of these expenditures.
The Clean Air Act Amendments of 1990 (the "Amendments") became effective on November 15, 1990. The Amendments address, among other things, "acid rain," visibility in certain specified areas, toxic air pollutants, and the nonattainment of national ambient air quality standards. With respect to "acid rain," the Amendments establish a system of sulfur dioxide emissions "allowances." Each existing utility unit is granted a certain number of "allowances." On March 5, 1993, the EPA promulgated rules listing allowance allocations applicable to Company-owned plants, which allocations will begin in the year 2000. Based on those allocations, APS will have sufficient allowances to permit continued operation of its plants at current levels without installing additional equipment. In addition, the Amendments require the EPA to set nitrogen oxides emissions limitations which would require certain plants to install additional pollution control equipment. On March 22, 1994, the EPA issued rules for nitrogen oxide emissions limitations which will require the Company to install additional pollution control equipment at the Four Corners Power Plant ("Four Corners"). In the year 2000 Four Corners must comply with either these or more stringent requirements which might be promulgated by the EPA. The EPA has until 1997 to set more stringent requirements. However, if Four Corners accelerates to 1997 compliance with these March 22, 1994 requirements, it can delay until 2008 compliance with any more stringent requirements which the EPA may set. APS has not yet determined how it will proceed; however, APS currently estimates the capital cost of complying by 1997 with the specified requirements will be approximately $16 million.
With respect to protection of visibility in certain specified areas, the Amendments require the EPA to complete a study by November 1995 concerning visibility impairment in those areas and identification of sources contributing to such impairment. Interim findings of this study have indicated that any beneficial effect on visibility as a result of the Amendments would be offset by expected population and industry growth. EPA has established a "Grand Canyon Visibility Transport Commission" to complete a study by November 1995 on visibility impairment in the "Golden Circle of National Parks" in the Colorado Plateau. NGS, the Cholla Power Plant ("Cholla"), and Four Corners are located near the "Golden Circle of National Parks." Based on the recommendations of the Commission, the EPA may require additional emissions controls at various sources causing visibility impairment in the "Golden Circle of National Parks" and may limit economic development in several western states. APS cannot currently estimate the capital expenditures, if any, which may be required as a result of the EPA studies and the Commission's recommendations.
With respect to hazardous air pollutants emitted by electric utility steam generating units, the Amendments require two studies. First, there will be a study to be completed by November 1994 of potential impacts of mercury emissions from such units and various other sources on public health and on the environment, including available control technologies. Second, the EPA will complete a general study by November 1995 concerning the necessity of regulating such units under the Amendments. Due to the lack of historical data, and because APS cannot speculate as to the ultimate requirements by the EPA, APS cannot currently estimate the capital expenditures, if any, which may be required as a result of these studies.
Certain aspects of the Amendments may require related expenditures by APS, such as permit fees, none of which APS expects to have a material impact on its financial position.
GENERATING FUEL
Coal, nuclear, gas, and other contributions to total net generation of electricity by APS in 1993, 1992, and 1991, and the average cost to APS of those fuels (in dollars per MWh), were as follows:
Other includes oil and hydro generation.
APS believes that Cholla has sufficient reserves of low sulfur coal committed to that plant for the next six years, the term of the existing coal contract, and sufficient reserves of low sulfur coal available for use to continue operating it for its useful life. APS also believes that Four Corners and NGS have sufficient reserves of low sulfur coal available for use by those plants to continue operating them for at least thirty years. The current sulfur content of coal being used at Four Corners, NGS, and Cholla is 0.8%, 0.6%, and 0.4%, respectively. In 1993, average prices paid for coal supplied from reserves dedicated under the existing contracts were relatively stable, although applicable contract clauses permit escalations under certain conditions. In addition, major price adjustments can occur from time to time as a result of contract renegotiation.
NGS and Four Corners are located on the Navajo Reservation and held under easements granted by the federal government as well as leases from the Navajo Tribe. See "Properties" in Item 2.
ITEM 2. PROPERTIES
APS' present generating facilities have an accredited capacity aggregating 4,022,410 kw, comprised as follows:
Capacity(kw) ------------ Coal: Units 1, 2, and 3 at Four Corners, aggregating........... 560,000 15% owned Units 4 and 5 at Four Corners, representing.... 222,000 Units 1, 2, and 3 at Cholla Plant, aggregating........... 590,000 14% owned Units 1, 2, and 3 at the Navajo Plant, representing........................................... 315,000 ----------- 1,687,000 ===========
Gas or Oil: Two steam units at Ocotillo, two steam units at Saguaro, and one steam unit at Yucca, aggregating............... 468,400(1) Eleven combustion turbine units, aggregating............. 500,600 Three combined cycle units, aggregating.................. 253,500 ----------- 1,222,500 ===========
Nuclear: 29.1% owned or leased Units 1, 2, and 3 at Palo Verde, representing........................................... 1,108,710 =========== Other........................................................ 4,200 =========== - ---------- (1) West Phoenix steam units (96,300 kw) are currently mothballed. --------------
APS' peak one-hour demand on its electric system was recorded on August 2, 1993 at 3,802,300 kw, compared to the 1992 peak of 3,796,400 kw recorded on August 17. Taking into account additional capacity then available to it under purchase power contracts as well as its own generating capacity, APS' capability of meeting system demand on August 2, 1993, computed in accordance with accepted industry practices, amounted to 4,505,000 kw, for an installed reserve margin of 16.7%. The power actually available to APS from its resources fluctuates from time to time due in part to planned outages and technical problems. The available capacity from sources actually operable at the time of the 1993 peak amounted to 4,099,500 kw, for a margin of 13.4%.
NGS and Four Corners are located on land held under easements from the federal government and also under leases from the Navajo Tribe. The risk with respect to enforcement of these easements and leases is not deemed by APS to be material. APS is dependent, however, in some measure upon the willingness and ability of the Navajo Tribe to honor its commitments. Certain of APS' transmission lines and almost all of its contracted coal sources are also located on Indian reservations. See "Generating Fuel" in Item 1.
Operation of each of the three Palo Verde units requires an operating license from the NRC. Full power operating licenses for Units 1, 2, and 3 were issued by the NRC in June 1985, April 1986, and November 1987, respectively. The full power operating licenses, each valid for a period of approximately 40 years, authorize APS, as operating agent for Palo Verde, to operate the three Palo Verde units at full power.
On August 18, 1986 and December 19, 1986, APS entered into a total of three sale and leaseback transactions under which it sold and leased back approximately 42% of its 29.1% ownership interest in Palo Verde Unit 2. The leases under each of the sale and leaseback transactions have initial lease terms expiring on December 31, 2015. Each of the leases also allows APS to extend the term of the lease and/or to repurchase the leased Unit 2 interest under certain circumstances at fair market value. The leases in the aggregate require annual payments of approximately $40 million through 1999, approximately $46 million in 2000, and approximately $49 million through 2015 (see Note 11 of the Notes to the Consolidated Financial Statements in Item 8).
See "Water Supply" in Item 1 with respect to matters having possible impact on the operation of certain of APS' power plants, including Palo Verde.
APS' construction plans are susceptible to changes in forecasts of future demand on its electric system and in its ability to finance its construction program. Although its plans are subject to change, APS does not presently intend to construct any new major baseload generating units for at least the next ten years. Important factors affecting APS' ability to delay the construction of new major generating units are continuing efforts to upgrade and improve the reliability of existing generating stations, system load diversity with other utilities, and continuing efforts in customer demand-side conservation and load management programs.
In addition to that available from its own generating capacity, APS purchases electricity from other utilities under various arrangements. One of the most important of these is a long-term contract with SRP which may be canceled by SRP on three years' notice and which requires SRP to make available, and APS to pay for, certain amounts of electricity that are based in large part on customer demand within certain areas now served by APS pursuant to a related territorial agreement. APS believes that the prices payable by it under the contract are fair to both parties. The generating capacity available to APS pursuant to the contract was 302,000 kw until May 1993, at which time the capacity increased to 304,000 kw. In 1993, APS received approximately 840,000 MWh of energy under the contract and paid approximately $40 million for capacity availability and energy received.
In September 1990, APS and PacifiCorp, an Oregon-based utility company, entered into certain agreements relating principally to sales and purchases of electric power and electric utility assets, and in July 1991, after regulatory approvals, APS sold Cholla Unit 4 to PacifiCorp for approximately $230 million. As part of the transaction, PacifiCorp agreed to make a firm system sale to APS for thirty years during APS' summer peak season in the amount of 175 megawatts for the first five years, increasing thereafter, at APS' option, up to a maximum amount equal to the rated capacity of Cholla Unit 4. After the first five years, all or part of the sale may be converted to a one-for-one seasonal capacity exchange. PacifiCorp has the right to purchase from APS up to 125 average megawatts of energy per year for thirty years. PacifiCorp and APS also entered into a 100 megawatt one-for-one seasonal capacity exchange to be effective upon the latter of January 1, 1996 or the completion of certain new transmission projects. In addition, PacifiCorp agreed to pay APS (i) $20 million upon commercial operation of 150 megawatts of peaking capacity constructed by APS and (ii) $19 million in connection with the construction of transmission lines and upgrades that will afford PacifiCorp 150 megawatts of northbound transmission rights. In addition, PacifiCorp secured additional firm transmission capacity of 30 megawatts over APS' system. In 1993, APS received 401,475 MWh of energy from PacifiCorp under these transactions and paid approximately $19 million for capacity availability and the energy received, and PacifiCorp paid approximately $2.7 million for 144,171 MWh.
See "El Paso Electric Company Bankruptcy" in Note 13 of the Notes to the Consolidated Financial Statements in Item 8 for a discussion of the filing by El Paso Electric Company ("EPEC") of a voluntary petition to reorganize under Chapter 11 of the Bankruptcy Code. EPEC has a joint ownership interest with APS and others in Palo Verde and Four Corners Units 4 and 5.
See Notes 6 and 12 of the Notes to the Consolidated Financial Statements in Item 8 with respect to property of APS not held in fee or held subject to any major encumbrance.
See "SunCor Development Company" and "El Dorado Investment Company" under the heading "Business of Non-Utility Subsidiaries" in Item 1 for a description of properties held by the non-utility subsidiaries of the Company.
GRAPHIC - ------- MAP OF THE STATE OF ARIZONA SHOWING APS' SERVICE AREA, THE LOCATION OF ITS MAJOR POWER PLANTS AND PRINCIPAL TRANSMISSION LINES, AND THE LOCATION OF TRANSMISSION LINES OPERATED BY APS FOR OTHERS. SEE APPENDIX FOR DETAILED DESCRIPTION.
ITEM 3.
ITEM 3. LEGAL PROCEEDINGS
APS
On June 29, 1990, a new Arizona state tax law was enacted, effective as of December 31, 1989, which adversely impacted APS' earnings in tax years 1990 through 1993 by an aggregate amount of approximately $82 million, before income taxes. On December 20, 1990, the Palo Verde participants, including APS, filed a lawsuit in the Arizona Tax Court, a division of the Maricopa County Superior Court, against the Arizona Department of Revenue, the Treasurer of the State of Arizona, and various Arizona counties, claiming, among other things, that portions of the new tax law are unconstitutional. (Arizona Public Service Company, et al. v. Apache County, et al., No. TX 90-01686 (Consol.), Maricopa County Superior Court). In December 1992, the court granted summary judgment to the taxing authorities, holding that the law is constitutional. APS has appealed this decision to the Arizona Court of Appeals. APS cannot currently predict the ultimate outcome of this matter.
See "Water Supply" and "Palo Verde Nuclear Generating Station" in Item 1 and "El Paso Electric Company Bankruptcy" in Note 13 of the Notes to the Company's Consolidated Financial Statements in Item 8 in regard to other pending or threatened litigation involving APS.
PINNACLE WEST
A lawsuit was filed in the United States District Court for the District of Arizona against the Company, its inside directors and certain of its officers on November 7, 1988 and was amended on December 15, 1988 to add the remaining directors and additional substantive claims. As amended, the complaint alleges violations of federal securities laws and Arizona securities, consumer fraud and other state laws in connection with certain actions of the Company and statements made on its behalf relating to the Company's diversification activities, future business prospects and dividends. The Court certified a class consisting of all purchasers of the Company's common stock between April 1, 1987 and October 7, 1988 (the alleged "Class Period"). The complaint sought unspecified compensatory and punitive damages as well as fees and costs.
On December 20, 1988 a lawsuit was filed in the United States District Court for the District of Arizona against the Company and certain officers and directors, alleging violations of federal securities laws and Arizona securities, consumer fraud and other state laws in connection with certain actions of the Company and statements made on its behalf relating to the Company's diversification activities, future business prospects and dividends. The lawsuit is substantially similar to the lawsuit referenced in the preceding paragraph. The plaintiffs, two individuals who claim to have purchased the Company's common stock between April 1, 1987 and October 7, 1988 (the alleged "Class Period"), requested unspecified compensatory and punitive damages as well as fees and costs. On October 2, 1989, the cases described in this and the preceding paragraph were consolidated.
On December 15, 1989 a shareholder derivative lawsuit was filed in the United States District Court for the District of Arizona naming the Company's directors as defendants and the Company as nominal defendant. The lawsuit alleges breach of fiduciary duties by the directors in connection with the Company's diversification activities, and further alleges violation of federal securities laws by one director in connection with the sale of MeraBank to the Company in 1986. The plaintiffs requested, on the Company's behalf, unspecified compensatory and punitive damages.
On April 22, 1991 a lawsuit was filed in the United States District Court for the District of Arizona by the Resolution Trust Corporation (the "RTC") against certain former officers and directors of MeraBank. The suit sought, among other things, damages in excess of $270 million, and alleged negligence, gross negligence, breach of fiduciary duty, breach of duty of loyalty and breach of contract with respect to the management and operation of MeraBank by the defendants beginning in the early 1980s. Although the Company was not a defendant, the Company agreed to advance reasonable attorneys' fees and expenses, in various amounts, to those defendants who served on the MeraBank Board of Directors at the request of the Company. The Company reserved the right to alter the amount of such advances or to terminate them as the case developed, and received undertakings from the persons receiving such advances to repay such amounts in the event that they are ultimately determined not to be entitled to indemnification. The Company has terminated future such advances as to certain of those defendants. In addition, in June and November of 1989 the Company's Board of Directors adopted resolutions whereby the Company agreed to indemnify the non-officer members of the MeraBank Board of Directors against claims brought against such individuals in their capacity as directors of MeraBank, for acts occurring on or after June and November 1989, the effective dates of the indemnification resolutions.
On December 30, 1993, and as the result of a negotiated settlement, the United States District Court for the District of Arizona entered orders and final judgments (1) dismissing the consolidated shareholder class litigation and shareholder derivative litigation initiated in 1988 and 1989, respectively, and described in the first three paragraphs under this heading and (2) partially dismissing the litigation initiated by the RTC and described in the immediately preceding paragraph. Two non-settling individuals who are pursuing independent claims against the RTC were not dismissed from the RTC litigation and have appealed the settlement. These individuals may attempt to look to the Company, its insurance carriers and others for indemnification of certain costs and damages. The Company believes that it has no obligation with respect to any such costs or damages. The settlement provides for for payments totaling $61.625 million, of which the Company's share is $5.75 million. A litigation reserve previously established by the Company is sufficient to cover the Company's share of the settlement. The balance of the settlement payment will be funded by the Company's insurers.
On January 18, 1991 a lawsuit was filed in the United States District Court, Southern District of Ohio, Western Division, against, among other parties, the Company and certain of its officers and directors, the Office of Thrift Supervision ("OTS"), the RTC and the Federal Deposit Insurance Corporation ("FDIC"). The amended complaint in this lawsuit alleges that the plaintiff purchased MeraBank subordinated debentures with a face amount of $1 million in 1987 in reliance upon the capital maintenance stipulation executed by the Company as a condition to the Company's acquisition of MeraBank. The plaintiff further alleges that the value of such debentures was impaired because of the Company's release from its purported obligations under the stipulation and the actions of the OTS in placing MeraBank in receivership. See Note 2 of the Notes to the Consolidated Financial Statements in Item 8 for additional information regarding the stipulation. The plaintiff is seeking damages in the approximate amount of $4.8 million. On August 2, 1991 the Ohio court issued an order dismissing the case with prejudice as to the Company and the officer/director defendants for lack of personal jurisdiction. The court also ordered the case dismissed with prejudice as to the OTS, the RTC and the FDIC. On October 1, 1991 the plaintiff appealed the court's order. On February 17, 1993, the United States Court of Appeals for the Sixth Circuit affirmed the entry of summary judgment in favor of the RTC, OTS, and FDIC, but reversed the district court's dismissal in favor of the Company and certain of its officers and directors. The Court of Appeals remanded the case to the district court for a determination of whether plaintiff had adequately pled its claims so that the district court could exercise personal jurisdiction. The district court was further instructed to consider whether the Southern District of Ohio was the proper venue for the suit. On June 8, 1993, the Ohio court ordered this case to be transferred to the District of Arizona. On August 17, 1993, the Company was served with a separate complaint filed by the same plaintiff in the District Court for the District of Arizona alleging claims under the Arizona Racketeering Act and the Arizona Consumer Fraud Act seeking compensatory damages in the amount of $1.2 million plus interest, punitive damages, treble damages, interest, attorneys' fees and costs. The plaintiff has voluntarily dismissed the Arizona Consumer Fraud Act claims; however, the Arizona Racketeering Act claims remain pending. The Company and the individual directors and officers believe that the lawsuit is without merit and will vigorously defend themselves.
On May 1, 1991, a lawsuit was filed in the United States District Court for the District of Arizona against the Company by another purchaser of the same issue of MeraBank subordinated debentures referred to in the immediately preceding paragraph. This plaintiff also claims to have purchased the debentures, with a face amount of approximately $12.4 million, in reliance upon the stipulation. The suit further alleges that the Company induced the plaintiff to retain its investment in the debentures by representing to the plaintiff that the Company would keep MeraBank capitalized in accordance with federal regulatory requirements. The suit alleges violations of federal and state securities laws, fraud, negligent representation, racketeering and intentional interference with contractual relations. The plaintiff seeks unspecified compensatory and punitive damages and has requested that the compensatory damages be trebled under Arizona's civil racketeering statute. The Company intends to vigorously defend itself in this action.
On December 22, 1993, Pinnacle West was served with a complaint filed by another purchaser of MeraBank subordinated debentures alleging claims substantially similar to the claims described in the preceding paragraph. The complaint, which was filed in the United States District Court for the District of Arizona, seeks compensation and punitive damages in an unspecified amount plus attorneys' fees and costs. The Company intends to vigorously defend itself in this action.
ITEM 4.
ITEM 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
No matter was submitted to a vote of security holders during the fourth quarter of the fiscal year covered by this report, through the solicitation of proxies or otherwise.
SUPPLEMENTAL ITEM. EXECUTIVE OFFICERS OF THE REGISTRANT
The Company's executive officers are as follows:
AGE AT NAME MARCH 1, 1994 POSITION(S) AT MARCH 1, 1994 - ---- ------------- ---------------------------- Michael S. Ash 40 Corporate Counsel Arlyn J. Larson 59 Vice President of Corporate Planning and Development Nancy E. Newquist 42 Vice President and Treasurer Henry B. Sargent 59 Executive Vice President and Chief Financial Officer(1) Richard Snell 63 Chairman of the Board of Directors, President and Chief Executive Officer(1) Faye Widenmann 45 Vice President of Corporate Relations and Administration and Secretary
- ---------- (1) Member of the Board of Directors.
The executive officers of the Company are elected no less often than annually and may be removed by the Board of Directors at any time. The terms served by the named officers in their current positions and the principal occupations (in addition to those stated in the table) of such officers for the past five years have been as follows:
Mr. Ash was elected Corporate Counsel of the Company in February 1991. He previously held the positions of Legal Counsel to the Company (December 1986 to February 1991) and Attorney in the APS Law Department (July 1983 to September 1985).
Mr. Larson was elected Vice President, Corporate Planning and Development in July 1986.
Ms. Newquist was elected Treasurer in June 1990 and as a Vice President in February 1994. Ms. Newquist also serves as Treasurer of APS, a position she was elected to in June 1993 after serving as Assistant Treasurer of APS since October 1992. From May 1987 to June 1990, Ms. Newquist served as the Company's Director of Finance.
Mr. Sargent was elected Executive Vice President and Chief Financial Officer of the Company in April 1985. Mr. Sargent was Executive Vice President and Chief Financial Officer of APS from September 1981 until July 1986. He is also a director of Magma Copper Company, Tucson, Arizona.
Mr. Snell was elected Chairman of the Board, President and Chief Executive Officer of the Company effective February 5, 1990. He was also elected Chairman of the Board of APS effective the same date. Previously, he was Chairman of the Board (1989-1992) and Chief Executive Officer (1989-1990) of Aztar Corporation, and Chairman of the Board, President and Chief Executive Officer of Ramada Inc., Phoenix, Arizona (1981-1989). Mr. Snell remains a director of Aztar Corporation and is also a director of Bank One Arizona Corporation, Phoenix, Arizona.
Ms. Widenmann was elected Secretary of the Company in 1985 and Vice President of Corporate Relations and Administration in November 1986. She was Secretary of APS from June 1983 until April 1987.
PART II
ITEM 5.
ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY AND RELATED STOCKHOLDER MATTERS
The Company's common stock is publicly held and is traded on the New York and Pacific Stock Exchanges. At the close of business on March 14, 1994, the Company's common stock was held of record by approximately 59,795 shareholders.
The chart below sets forth the common stock price ranges on the composite tape, as reported in the Wall Street Journal for 1993 and 1992. There were no dividends declared or paid on or in respect of the Company's common stock during 1992 and the first three quarters of 1993. A dividend of $.20 per share was declared and paid on the Company's common stock during the fourth quarter of 1993.
COMMON STOCK PRICE RANGES - ------------------------------------------------------------------------------
1992 HIGH LOW - ------------------------------------------- 1st Quarter 18 1/4 16 3/4 2nd Quarter 18 3/8 16 7/8 3rd Quarter 20 17 7/8 4th Quarter 20 1/2 19 1/8 - ------------------------------------------- - ------------------------------------------- 1st Quarter 21 3/4 19 5/8 2nd Quarter 23 1/2 20 7/8 3rd Quarter 25 1/4 23 1/8 4th Quarter 24 3/8 20 3/8 - -------------------------------------------
ITEM 7.
ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion relates to Pinnacle West Capital Corporation (the "Company" or "Pinnacle West") and its subsidiaries: Arizona Public Service Company ("APS"), SunCor Development Company ("SunCor") and El Dorado Investment Company ("El Dorado"). The discussion also relates to the discontinued operations of MeraBank, A Federal Savings Bank ("MeraBank").
CAPITAL NEEDS AND RESOURCES
Parent Company
During the past three years, Pinnacle West's primary cash needs were for the payment of interest and prepayment of principal on its long-term debt (see Note 6 of Notes to Consolidated Financial Statements). Additional cash needs in 1993 were related to the fourth quarter restoration of common stock dividends.
Dividends from APS have been Pinnacle West's primary source of cash. Tax allocations within the consolidated group and net operating loss carryforwards associated with MeraBank have also been sources of cash.
The non-utility subsidiaries (SunCor and El Dorado) are also expected to contribute to Pinnacle West's cash flow.
Pinnacle West prepaid substantial amounts of its parent-level debt in each of the last three years. Management expects Pinnacle West to have sufficient cash flow available for mandatory and optional debt repayments to allow parent company debt to be reduced from $564 million at the end of 1993 to approximately $300 million by year-end 1995.
At the end of 1993, Pinnacle West had a $40 million liquidity facility as summarized in Note 5 of Notes to Consolidated Financial Statements; no borrowings were outstanding thereunder.
APS
APS' capital needs consist primarily of construction expenditures and required repayments or redemptions of long-term debt and preferred stock. The capital resources available to meet these requirements include funds provided by operations and external financings.
Present construction plans exclude any major baseload generating plants for at least the next ten years. In general, most of the construction expenditures are for expanding transmission and distribution capabilities to meet customer growth, upgrading existing facilities, and environmental purposes. Construction expenditures are anticipated to be $279 million, $302 million and $293 million for 1994, 1995 and 1996, respectively. These amounts include nuclear fuel expenditures, but exclude capitalized property taxes and capitalized interest costs.
In the 1991 through 1993 period, APS funded all of its capital expenditures (construction expenditures and capitalized property taxes) with internally generated funds, after the payment of dividends. For the period 1994 through 1996, APS estimates that it will fund substantially all of its capital expenditures with internally generated funds, after the payment of dividends.
During 1993, APS redeemed or repurchased approximately $637 million of long-term debt and preferred stock, of which approximately $527 million was optional. Refunding obligations for preferred stock, long-term debt, a capitalized lease obligation, and certain anticipated early redemptions are expected to total approximately $187 million, $135 million and $4 million for the years 1994, 1995 and 1996, respectively.
APS currently expects to issue in 1994 a total of approximately $125 million of long-term debt (primarily first mortgage bonds) and approximately $125 million of preferred stock. Of this, APS issued on March 2, 1994, $100 million of its First Mortgage Bonds, 6 5/8% series due 2004, and applied the net proceeds to the repayment of short-term debt that had been incurred for the redemption of preferred stock and for general corporate purposes. APS expects that substantially all of the net proceeds of the balance of the securities to be issued during 1994 will be used for the retirement of outstanding debt and preferred stock. On March 1, 1994, APS redeemed all of the outstanding shares of its $8.80 Cumulative Preferred Stock, Series K ($100 Par Value) in the amount of $14.21 million. As of April 4, 1994, APS will be redeeming all $60.264 million of its outstanding First Mortgage Bonds, 10 3/4% Series due 2019.
Provisions in APS' mortgage bond indenture and articles of incorporation require certain coverage ratios to be met before APS can issue additional first mortgage bonds or preferred stock. In addition, the mortgage bond indenture limits the amount of additional bonds which may be issued to a percentage of net property additions, to property previously pledged as security for certain bonds that have been redeemed or retired, and/or to cash deposited with the mortgage bond trustee. After giving effect to the transactions described in the preceding paragraph, as of December 31, 1993, APS estimates that the mortgage bond indenture and the articles of incorporation would have allowed it to issue up to approximately $1.2 billion and $986 million of additional first mortgage bonds and preferred stock, respectively.
The Arizona Corporation Commission (the "ACC") has authority over APS with respect to the issuance of long-term debt and equity securities. Existing ACC orders allow APS to have up to approximately $2.6 billion in long-term debt and approximately $501 million of preferred stock outstanding at any one time.
Management does not expect any of the foregoing restrictions to limit APS' ability to meet its capital requirements.
As of December 31, 1993, APS had credit commitments from various banks totalling approximately $302 million, which were available either to support the issuance of commercial paper or to be used for bank borrowings. Commercial paper borrowings totalling $148 million were outstanding at the end of 1993.
Non-Utility Subsidiaries
During the past three years, the non-utility subsidiaries generally financed all of their operations through cash flow from operations and financings that did not involve Pinnacle West.
SunCor's capital needs consist primarily of construction expenditures, which are expected to approximate $33 million, $18 million and $14 million for 1994, 1995 and 1996, respectively. Capital resources available to meet these requirements include funds provided by operations and external financings.
On March 2, 1994, SunCor issued $25 million of Collateralized Mortgage Bonds, due in 2004. The bonds are secured by specified parcels of real property and bear variable interest based on London Interbank Offered Rate (LIBOR). Simultaneously, $6 million of 12% debt due in 1997 was prepaid.
Management expects El Dorado's internal cash flows to be sufficient to fund its operations for the foreseeable future.
RESULTS OF OPERATIONS
1993 Compared to 1992
Pinnacle West reported income from continuing operations of $170.0 million in 1993 compared to $150.4 million in 1992, for an increase of $19.6 million. The primary factor contributing to this increase was lower interest expense. Interest costs in 1993 were $22.5 million lower than 1992 due to refinancing debt at lower rates, lower average debt balances and lower interest rates on APS' variable-rate debt. Partially offsetting the lower interest expense were increased taxes and higher utility operating expenses.
Electric operating revenues were up $16.6 million in 1993 on sales volumes of 20.1 million megawatt-hours (MWh) compared to 20.6 million MWh in 1992. Although revenues increased $45.3 million due to growth in the residential and business customer classes, these increases were largely offset by milder than normal weather and reduced interchange sales to other utilities.
Fuel and purchased power costs increased $15.5 million in 1993 due to Palo Verde outages and reduced power operations (see Note 13 of Notes to Consolidated Financial Statements). Partially offsetting the $15.5 million were miscellaneous items resulting in a net increase of $13.3 million over 1992. These increases are reflected currently in earnings because APS does not have a fuel adjustment clause as part of its retail rate structure. The net result of electric operating revenues less fuel and purchased power expense was an increase of $3.3 million comparing 1993 to 1992.
In 1993, utility operations expense increased $11.8 million over 1992 levels primarily due to the implementation of new accounting standards for postemployment benefits and postretirement benefits other than pensions, which added $17 million to expense in 1993 (see Note 9 of Notes to Consolidated Financial Statements). Partially offsetting these factors were lower power plant operating costs, lower rent expense and lower costs for an employee gainsharing plan.
Real estate operating revenues and operating expenses were up $12.3 million and $10.9 million, respectively, in 1993 due to increased sales of residential lots.
1992 Compared to 1991
Income from continuing operations in 1992 was $150.4 million compared to a loss in 1991 of $340.3 million. This was primarily due to the after-tax write- offs of $407 million in 1991 resulting from a rate case settlement with the ACC (see "Rate Case Settlement" in Note 3 of Notes to Consolidated Financial Statements). Excluding the effects of the write-offs, income from continuing operations increased by $83.7 million in 1992 as a result of several factors, including higher revenues, lower interest costs and lower utility operations expenses. Partially offsetting these factors were higher fuel and purchased power costs and higher utility maintenance expenses.
Electric operating revenues were up $154.4 million during 1992 on sales volumes of 20.6 million MWh compared to 20.0 million MWh in 1991. The volume increase of $48.6 million was largely due to growth in residential and business customer classes and increased sales due to more normal weather as compared to 1991. A price-related increase of $85.9 million was largely due to an increase in retail base rates effective December 6, 1991 and a higher average price for interchange sales to other utilities. Also contributing to the increase in 1992 was a $19.9 million reversal of a non-cash refund obligation recorded in December, 1991 (see Note 3 of Notes to Consolidated Financial Statements).
Real estate revenues increased in 1992 primarily due to the sale of a golf course.
Interest costs were $47.8 million lower in 1992 as compared to 1991 due to lower average debt balances, lower interest rates on APS' variable-rate debt and lower interest rates on refinanced debt.
Fuel expenses increased in 1992 over 1991 by $13.4 million as a result of increased generation due to increased retail and interchange sales, and increased gas prices. These increases were partially offset by lower prices for coal and uranium. The increase in the purchased power component of fuel expenses was due to favorable market prices.
Utility operations costs were $15.3 million lower in 1992 as compared to 1991 primarily due to lower operating costs at Palo Verde, lower fossil plant overhaul costs and other miscellaneous cost reductions. Partially offsetting these were an obligation recorded for an employee gainsharing plan and higher nuclear refueling outage costs.
Non-Cash Income
Net income reflects accounting practices required for regulated public utilities and represents a composite of cash and non-cash items, including Allowance for Funds Used During Construction (AFUDC), accretion income on Palo Verde Unit 3 and the reversal of a refund obligation related to the Palo Verde write-off (see "Consolidated Statements of Cash Flows" and Note 3 of Notes to Consolidated Financial Statements). APS recorded after-tax accretion income of $45.3 million, $40.7 million and $3.2 million in 1993, 1992 and 1991, respectively. APS also recorded refund obligation reversals in electric operating revenues of $12.9 million after tax in each of the years 1993 and 1992 and $0.9 million in 1991. APS will record after-tax accretion income and refund obligation reversals of $20.3 million and $5.6 million, respectively, through June 5, 1994.
Palo Verde Nuclear Generating Station
As APS continues its investigation and analysis of the Palo Verde steam generators, certain corrective actions are being taken. These include chemical cleaning, operating the units at reduced temperatures, and for some periods, operating the units at approximately 86% power. So long as three units are involved in mid-cycle outages and are operated at the 86% level, APS will incur an average of approximately $2 million per month (before income taxes) for additional fuel and purchased power costs. See "Palo Verde Tube Cracks" in Note 13 of Notes to Consolidated Financial Statements for a more detailed discussion.
Accounting Issues
Note 4 of Notes to Consolidated Financial Statements describes a new accounting standard for income taxes which required the recognition in 1993 of $19.3 million of state tax benefits related to net operating loss carryforwards.
Discontinued Operations
Income from discontinued operations of $6.0 million and $153.5 million in 1992 and 1991, respectively, resulted from tax benefits recorded in connection with the MeraBank settlement.
ITEM 8.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
INDEX TO FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES
Page ---------- Report of Management.............................................. 25
Independent Auditors' Report...................................... 26
Statements of Income for each of the three years in the period ended December 31, 1993......................................... 27
Balance Sheets -- December 31, 1993 and 1992...................... 28, 29
Statements of Cash Flows for each of the three years in the period ended December 31, 1993......................................... 30
Statements of Retained Earnings for each of the three years in the period ended December 31, 1993.................................. 31
Notes to Financial Statements..................................... 32
Financial Statement Schedules for each of the three years in the period ended December 31, 1993
Schedule V -- Property, Plant and Equipment.................. 50
Schedule VI -- Accumulated Depreciation, Depletion and Amortization of Property, Plant and Equipment.............. 53
Schedule VIII -- Valuation and Qualifying Accounts for the years ended December 31, 1993, 1992 and 1991............... 56
Schedule IX -- Short-Term Borrowings......................... 57
See Note 14 of Notes to Consolidated Financial Statements for the selected quarterly financial data required to be presented in this Item.
REPORT OF MANAGEMENT
The primary responsibility for the integrity of the Company's financial information rests with management, which has prepared the accompanying financial statements and related information. Such information was prepared in accordance with generally accepted accounting principles appropriate in the circumstances, based on managements best estimates and judgments and giving due consideration to materiality. These financial statements have been audited by independent auditors and their report is included.
Management maintains and relies upon systems of internal accounting controls, which are periodically reviewed by both the Company's internal auditors and its independent auditors to test for compliance. Reports issued by the internal auditors are released to management, and such reports, or summaries thereof, are transmitted to the Audit Committee of the Board of Directors and the independent auditors on a timely basis.
The Audit Committee, composed solely of outside directors, meets periodically with the internal auditors and independent auditors (as well as management) to review the work of each. The internal auditors and independent auditors have free access to the Audit Committee, without management present, to discuss the results of their audit work.
Management believes that the Company's systems, policies and procedures provide reasonable assurance that operations are conducted in conformity with the law and with management's commitment to a high standard of business conduct.
Richard Snell Henry B. Sargent Chairman & President Executive Vice President & Chief Financial Officer
INDEPENDENT AUDITORS' REPORT
We have audited the accompanying consolidated balance sheets of Pinnacle West Capital Corporation and its subsidiaries as of December 31, 1993 and 1992 and the related consolidated statements of income, retained earnings and cash flows for each of the three years in the period ended December 31, 1993. Our audits also included the financial statement schedules listed in the Index at Item 8. These financial statements and financial statement schedules are the responsibility of the Company's management. Our responsibility is to express an opinion on these financial statements and financial statement schedules based on our audits.
We conducted our audits in accordance with generally accepted auditing standards. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement. An audit includes examining, on a test basis, evidence supporting the amounts and disclosures in the financial statements. An audit also includes assessing the accounting principles used and significant estimates made by management, as well as evaluating the overall financial statement presentation. We believe that our audits provide a reasonable basis for our opinion.
In our opinion, such consolidated financial statements present fairly, in all material respects, the financial position of Pinnacle West Capital Corporation and its subsidiaries at December 31, 1993 and 1992 and the results of their operations and their cash flows for each of the three years in the period ended December 31, 1993 in conformity with generally accepted accounting principles. Also, in our opinion, such financial statement schedules, when considered in relation to the basic financial statements taken as a whole, present fairly in all material respects the information set forth herein.
As discussed in Note 4 of Notes to Consolidated Financial Statements, the Company changed its method of accounting for income taxes effective January 1, 1993 to conform with Statement of Financial Accounting Standards No. 109.
Deloitte & Touche Phoenix, Arizona February 21, 1994
PINNACLE WEST CAPITAL CORPORATION
CONSOLIDATED STATEMENTS OF INCOME (DOLLARS IN THOUSANDS, EXCEPT PER SHARE AMOUNTS)
YEAR ENDED DECEMBER 31, ----------------------------------------- 1993 1992 1991 ------------- ------------ ------------ Operating Revenues Electric......................... $ 1,686,290 $ 1,669,679 $ 1,515,289 Provision for rate refund (Note 3)....................... -- -- (53,436) Real estate...................... 32,248 19,959 12,697 ------------- ------------ ------------ Total........................ 1,718,538 1,689,638 1,474,550 ------------- ------------ ------------ Fuel Expenses Fuel for electric generation..... 231,434 230,194 223,983 Purchased power.................. 69,112 57,007 49,788 ------------- ------------ ------------ Total........................ 300,546 287,201 273,771 ------------- ------------ ------------ Operating Expenses Utility operations and maintenance.................... 401,216 390,512 401,736 Real estate operations........... 38,220 27,309 25,482 Depreciation and amortization.... 223,558 220,076 219,010 Taxes other than income taxes (Note 11)...................... 222,345 217,063 215,541 Palo Verde cost deferral (Notes 1 and 3)................ -- -- (70,886) Disallowed Palo Verde costs (Note 3)....................... -- -- 577,145 ------------- ------------ ------------ Total........................ 885,339 854,960 1,368,028 ------------- ------------ ------------ Operating Income (Loss)............ 532,653 547,477 (167,249) ------------- ------------ ------------ Other Income (Deductions) Allowance for equity funds used during construction (Note 1)... 2,326 3,103 3,902 Palo Verde cost deferral (Notes 1 and 3)................ -- -- 63,068 Palo Verde accretion income (Note 3)....................... 74,880 67,421 5,306 Interest on long-term debt....... (245,961) (272,240) (316,282) Other interest................... (16,505) (12,718) (16,447) Allowance for borrowed funds used during construction (Note 1)... 4,153 4,492 6,636 Preferred stock dividend requirements of APS............ (30,840) (32,452) (33,404) Other -- net..................... (2,282) (13,045) (31,463) ------------- ------------ ------------ Total........................ (214,229) (255,439) (318,684) ------------- ------------ ------------ Income (Loss) From Continuing Operations Before Income Taxes.............. 318,424 292,038 (485,933) Income Tax Expense (Benefit) (Note 4)......................... 148,446 141,598 (145,616) ------------- ------------ ------------ Income (Loss) From Continuing Operations....................... 169,978 150,440 (340,317)
Income From Discontinued Operations (Note 2)......................... -- 6,000 153,455 Cumulative Effect of Change in Accounting for Income Taxes...... 19,252 -- -- ------------- ------------ ------------ Net Income (Loss).................. $ 189,230 $ 156,440 $ (186,862) ============= ============ ============ Average Common Shares Outstanding.. 87,241,899 87,044,180 86,937,052 Earnings (Loss) Per Average Common Share Outstanding Continuing operations.......... $ 1.95 $ 1.73 $ (3.91) Discontinued operations........ -- 0.07 1.76 Accounting change.............. 0.22 -- -- ------------- ------------ ------------ Total........................ $ 2.17 $ 1.80 $ (2.15) ============= ============ ============
Dividends Declared Per Share....... $ 0.20 $ -- $ -- ============= ============ ============
See Notes to Consolidated Financial Statements.
PINNACLE WEST CAPITAL CORPORATION
CONSOLIDATED STATEMENTS OF INCOME (THOUSANDS OF DOLLARS)
DECEMBER 31, ---------------------- 1993 1992 ---------- ---------- ASSETS Current Assets Cash and cash equivalents........................... $ 52,127 $ 87,926 Customer and other receivables -- net............... 126,343 157,433 Accrued utility revenues (Note 1)................... 60,356 51,517 Materials and supplies (at average cost)............ 96,174 95,978 Fossil fuel (at average cost)....................... 34,220 36,668 Other current assets................................ 13,782 8,000 Deferred income taxes (Note 4)...................... 100,234 105,348 ---------- ---------- Total current assets.............................. 483,236 542,870 ---------- ---------- Investments and Other Assets Real estate investments -- net...................... 402,873 394,527 Other assets........................................ 136,074 142,309 ---------- ---------- Total investments and other assets................ 538,947 536,836 ---------- ---------- Utility Plant (Notes 6, 11 and 12) Electric plant in service, including nuclear fuel... 6,462,589 6,335,327 Construction work in progress....................... 197,556 162,168 ---------- ---------- Total utility plant............................... 6,660,145 6,497,495 Less accumulated depreciation and amortization...... 2,058,895 1,973,698 ---------- ---------- Net utility plant................................. 4,601,250 4,523,797 ---------- ---------- Deferred Debits Regulatory asset for income taxes (Note 4).......... 585,294 -- Palo Verde Unit 3 cost deferral (Notes 1 and 3)..... 301,748 310,908 Palo Verde Unit 2 cost deferral (Note 1)............ 177,998 184,061 Other deferred debits............................... 268,326 172,004 ---------- ---------- Total deferred debits............................. 1,333,366 666,973 ---------- ---------- Total Assets.......................................... $6,956,799 $6,270,476 ========== ==========
See Notes to Consolidated Financial Statements.
PINNACLE WEST CAPITAL CORPORATION
CONSOLIDATED BALANCE SHEETS (THOUSANDS OF DOLLARS)
DECEMBER 31, ----------------------- 1993 1992 ---------- ----------- LIABILITIES AND EQUITY Current Liabilities Accounts payable................................... $ 97,489 $ 105,718 Accrued taxes...................................... 96,303 117,694 Accrued interest................................... 57,674 58,579 Short-term borrowings (Note 5)..................... 148,000 195,000 Current maturities of long-term debt (Note 6)...... 78,841 94,217 Other current liabilities.......................... 60,845 78,909 ---------- ----------- Total current liabilities........................ 539,152 650,117 ---------- ----------- Non-Current Liabilities Long-term debt less current maturities (Note 6).... 2,633,620 2,774,305 Other liabilities.................................. 8,246 9,449 ---------- ----------- Total non-current liabilities.................... 2,641,866 2,783,754 ---------- ----------- Deferred Credits and Other Deferred income taxes (Note 4)..................... 1,278,673 578,020 Deferred investment tax credit..................... 127,331 133,359 Unamortized gain -- sale of utility plant.......... 107,344 116,167 Other deferred credits............................. 221,762 133,138 ---------- ----------- Total deferred credits and other................. 1,735,110 960,684 ---------- ----------- Commitments and Contingencies (Note 13)
Minority Interests Non-redeemable preferred stock of APS (Note 7)..... 193,561 168,561 ---------- ----------- Redeemable preferred stock of APS (Note 7)......... 197,610 225,635 ---------- ----------- Common Stock Equity (Note 8) Common stock, no par value; authorized 150,000,000 shares; issued and outstanding 87,423,817 in 1993 and 87,161,872 in 1992........................... 1,642,783 1,646,772 Retained earnings (deficit)........................ 6,717 (165,047) ---------- ----------- Total common stock equity........................ 1,649,500 1,481,725 ---------- ----------- Total Liabilities and Equity......................... $6,956,799 $6,270,476 ========== ===========
PINNACLE WEST CAPITAL CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS (THOUSANDS OF DOLLARS)
YEAR ENDED DECEMBER 31, -------------------------------------- 1993 1992 1991 ------------ ----------- ----------- CASH FLOWS FROM OPERATING ACTIVITIES (Note 1) Income (loss) from continuing operations.......................... $ 169,978 $ 150,440 $ (340,317) Items not requiring cash Depreciation and amortization....... 258,562 259,637 268,153 Deferred income taxes -- net........ 139,725 84,146 (128,863) Palo Verde cost deferral (Notes 1 and 3)............................ -- -- (133,954) Provision for rate refund -- net (Note 3).......................... (21,374) (21,374) 52,057 Disallowed Palo Verde costs (Note 3) -- -- 577,145 Palo Verde accretion income (Note 3) (74,880) (67,421) (5,306) Other -- net........................ (168) (1,829) (4,235) Changes in current assets and liabilities Accounts receivable -- net.......... 31,090 (31,715) 18,006 Accrued utility revenues............ (8,839) (7,055) 1,004 Materials, supplies and fossil fuel. 2,252 5,094 (8,490) Other current assets................ (5,782) 2,042 (478) Accounts payable.................... (27,196) 9,547 18,866 Accrued taxes....................... (21,391) 45,962 (18,902) Accrued interest.................... (905) (16,593) (3,588) Other current liabilities........... (18,408) (16,549) 3,364 Additions to real estate............ (29,290) (12,647) (18,593) Sales of real estate................ 21,396 14,622 7,787 Other -- net........................ 34,292 5,973 4,407 ------------ ----------- ----------- Net Cash Flow Provided By Operating Activities.......................... 449,062 402,280 288,063 ------------ ----------- -----------
CASH FLOWS FROM INVESTING ACTIVITIES Capital expenditures.................. (234,944) (224,419) (182,687) Allowance for equity funds used during construction........................ 2,326 3,103 3,902 Sale of property (Note 3)............. 89 5,480 233,875 Other -- net.......................... 1,609 (6,555) (2,630) ------------ ----------- ----------- Net Cash Flow Provided By (Used For) Investing Activities................ (230,920) (222,391) 52,460 ------------ ----------- -----------
CASH FLOWS FROM FINANCING ACTIVITIES Issuance of long-term debt............ 535,893 649,165 485,844 Issuance of preferred stock........... 72,644 24,781 49,375 Short-term borrowings -- net.......... (47,000) 195,000 (159,000) Dividends paid on common stock........ (17,466) -- -- Repayment of long-term debt........... (711,241) (1,109,181) (593,252) Repayment of preferred stock.......... (78,663) (27,850) (15,175) Other -- net.......................... (8,108) 2,407 6,042 ------------ ----------- ----------- Net Cash Flow Used For Financing Activities.......................... (253,941) (265,678) (226,166) ------------ ----------- -----------
Net Cash Flow......................... (35,799) (85,789) 114,357
Cash and Cash Equivalents at Beginning of Year............................. 87,926 173,715 59,358 ------------ ----------- ----------- Cash and Cash Equivalents at End of Year................................ $ 52,127 $ 87,926 $ 173,715 ============ =========== ===========
See Notes to Consolidated Financial Statements.
PINNACLE WEST CAPITAL CORPORATION
CONSOLIDATED STATEMENTS OF RETAINED EARNINGS (THOUSANDS OF DOLLARS)
YEAR ENDED DECEMBER 31, ----------------------------------- 1993 1992 1991 ----------- ---------- ---------- Retained Earnings (Deficit) at Beginning of Year................................ $ (165,047) $ (321,487) $ (134,625) Net Income (Loss)........................ 189,230 156,440 (186,862) Common Stock Dividends................... (17,466) -- -- ----------- ---------- ---------- Retained Earnings (Deficit) at End of Year................................... $ 6,717 $ (165,047) $ (321,487) =========== ========== ==========
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
A. CONSOLIDATION
The consolidated financial statements include the accounts of Pinnacle West Capital Corporation and its subsidiaries: Arizona Public Service Company, an electric utility; SunCor Development Company, a real estate development company; and El Dorado Investment Company, a venture capital firm. Certain prior year balances have been reclassified to conform to the 1993 presentation.
B. UTILITY PLANT AND DEPRECIATION
Utility plant represents the buildings, equipment and other facilities used to provide electric service. The cost of utility plant includes labor, material, contract services and other related items and an allowance for funds used during construction. The cost of retired depreciable utility plant, plus removal costs less salvage realized, is charged to accumulated depreciation.
Depreciation on utility property is provided on a straight-line basis. The applicable rates for 1991 through 1993 ranged from 0.84% to 15.00%, which resulted in annual composite rates of 3.37%. Depreciation and amortization of non-utility property and equipment are provided over the estimated useful lives of the related assets, ranging from 3 to 33.3 years.
C. REVENUES
Electric operating revenues are recognized on the accrual basis and include estimated amounts for service rendered but unbilled at the end of each accounting period.
D. ALLOWANCE FOR FUNDS USED DURING CONSTRUCTION
AFUDC represents the cost of debt and equity funds used to finance construction of utility plant. Plant construction costs, including AFUDC, are recovered in authorized rates through depreciation when completed projects are placed into commercial operation. AFUDC does not represent current cash earnings.
AFUDC has been calculated using composite rates of 7.20% for 1993, 10.00% for 1992 and 10.15% for 1991. APS compounds AFUDC semiannually and ceases to accrue AFUDC when construction work is completed and the property is placed in service.
E. INCOME TAXES
Pinnacle West and its subsidiaries file a consolidated U.S. income tax return. Provisions for income tax are made by each subsidiary as if separate income tax returns were filed. The difference, if any, between these provisions and consolidated income tax expense is allocated to Pinnacle West. Investment tax credits were deferred and are being amortized to other income over the estimated lives of the related assets as directed by the ACC. In 1993, Pinnacle West adopted Statement of Financial Accounting Standards (SFAS) No. 109, "Accounting for Income Taxes" (see Note 4).
F. REACQUIRED DEBT COSTS
APS amortizes gains and losses on reacquired debt over the remaining life of the original debt, consistent with ratemaking.
G. NUCLEAR FUEL AND DECOMMISSIONING COSTS
Nuclear fuel is charged to fuel expense using the unit-of-production method under which the number of units of thermal energy produced in the current period is related to the total thermal units expected to be produced over the remaining life of the fuel.
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
In 1993, APS recorded $6.5 million for decommissioning expense. Based on the most recent site-specific study to completely remove all facilities, APS expects to record $11.4 million for decommissioning expense in 1994. APS estimates it will cost approximately $2.1 billion ($407 million in 1993 dollars), over a thirteen-year period beginning in 2023, to decommission its 29.1% interest in Palo Verde. Decommissioning costs are charged to expense over the respective units operating license term and included in the accumulated depreciation balance until Palo Verde is retired from service.
As required by the ACC, APS has established external trust accounts into which quarterly deposits are made for decommissioning. As of December 31, 1993, APS has deposited a total of $35.0 million. The trust accounts are included in "Investments and Other Assets" on the Consolidated Balance Sheets and have accumulated a $44.7 million balance at December 31, 1993, including investment earnings.
H. STATEMENTS OF CASH FLOWS
Temporary cash investments and marketable securities with an initial maturity of three months or less are considered to be cash equivalents for purposes of the Consolidated Statements of Cash Flows. During 1993, 1992 and 1991, Pinnacle West and its subsidiaries paid interest, net of amounts capitalized, of $243.9 million, $286.4 million and $305.4 million, respectively. Income taxes paid were $45.3 million, $33.8 million and $19.7 million, respectively; and dividends paid on preferred stock of APS were $30.9 million, $32.6 million and $33.1 million, respectively.
I. PALO VERDE COST DEFERRALS
As authorized by the ACC, APS deferred operating costs (excluding fuel) and financing costs of Palo Verde Units 2 and 3 from each units commercial operation date until the date each unit was included in a rate order. The deferrals are being amortized and recovered through rates over thirty-five year periods.
2. DISCONTINUED OPERATIONS
In 1989, a settlement was reached which resolved claims made by certain federal agencies with respect to MeraBank, resulting in a $450 million capital infusion by Pinnacle West into MeraBank. The settlement released Pinnacle West from its purported obligations under a capital maintenance stipulation relating to MeraBank. Because of certain unresolved federal income tax issues, Pinnacle West could not at the time record an income tax benefit related to the loss incurred as a result of the settlement. In January 1992, the Internal Revenue Service issued a ruling which allowed Pinnacle West to deduct, for federal income tax purposes, its remaining investment in MeraBank including the capital infusion. As a result, Pinnacle West recorded income from discontinued operations in 1991 of $153.5 million representing the tax benefit of a federal net operating loss (NOL) carryforward.
In 1992, Pinnacle West recorded $6 million of income from discontinued operations representing the recognition of a portion of the state NOL carryforward.
3. REGULATORY MATTERS
RATE CASE SETTLEMENT
In December 1991, APS and the ACC reached a settlement in the retail rate case that had been pending before the ACC since January 1990. The ACC authorized an annual net revenue increase of $66.5 million, or approximately 5.2%. In turn, APS wrote off $577.1 million of costs associated with Palo
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Verde and recorded a refund obligation of $53.4 million. The after-tax impact of these adjustments reduced 1991 net income by $407 million. A discussion of the components of the disallowance follows.
Prudence Audit
The ACC closed its prudence audit of Palo Verde and APS wrote off $142 million ($101.3 million after tax) of construction costs relating to Palo Verde Units 1, 2 and 3 and $13.3 million ($8.6 million after tax) of deferred costs relating to the prudence audit.
Interim or Temporary Revenues
The ACC removed the interim and temporary designation on $385 million of revenues collected by APS from 1986 through 1991 that had been previously authorized for Palo Verde Units 1 and 2. APS recorded a refund obligation to customers of $53.4 million ($32.3 million after tax) related to the Palo Verde write-off discussed above. The refund obligation has been used to reduce the amount of annual rate increase granted rather than require specific customer refunds and is being reversed over thirty months beginning December 1991. During 1993, 1992 and 1991 after-tax refund obligation reversals recorded by APS as electric operating revenue were $12.9 million, $12.9 million and $0.9 million, respectively. APS will record $5.6 million after tax in 1994.
Excess Capacity Issue
The ACC deemed a portion of Palo Verde Unit 3 to be excess capacity and, accordingly, did not recognize the related Unit 3 costs for ratemaking purposes. This action effectively disallows for thirty months a return on approximately $475 million of APS' investment in Unit 3. APS recognized a charge of $181.2 million ($109.5 million after tax), representing the present value of the lost cash flow and to that extent temporarily discounted the carrying value of Unit 3.
In accordance with generally accepted accounting principles, APS is recording, over the thirty-month period, accretion income on Unit 3 in the aggregate amount of the discount. During 1993, 1992 and 1991 APS recorded after-tax accretion income of $45.3 million, $40.7 million and $3.2 million, respectively. APS will record $20.3 million after tax in 1994.
In December 1991, APS stopped deferring Unit 3 costs and recorded a $240.6 million ($155.3 million after tax) write-off of Unit 3 cost deferrals due to a portion of Unit 3 being deemed excess capacity. At that time, APS began amortizing to expense and recovering in rates the remaining $320 million balance of the deferrals over a thirty-five year period as approved by the ACC.
Future Retail Rate Increase
APS agreed not to file a new rate application before December 1993 and the ACC agreed to expedite the processing of a future rate application. APS and the ACC also agreed on an average unit sales price ceiling of 9.585 cents per kilowatt-hour in this future rate application, if filed prior to January 1, 1995. APS' 1993 average unit sales price was approximately 9 cents per kilowatt-hour. This ceiling may be adjusted for the effects of significant changes in laws, regulatory requirements or APS' cost of equity capital. Management believes that the unit sales price ceiling will not adversely impact APS' future earnings and has not yet determined when a rate case may be filed.
Dividend Payments
APS agreed to limit its annual common stock dividends to Pinnacle West to $170 million through December 1993.
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
SALE OF CHOLLA 4
July 1991, APS sold Unit 4 of the Cholla Power Plant to PacifiCorp for approximately $230 million. The resulting after-tax gain of approximately $20 million was deferred and is being amortized as a reduction to operations expense over a four-year period in accordance with an ACC order. The transaction also provides for transmission access and electrical energy sales and exchanges between APS and PacifiCorp.
4. INCOME TAX EXPENSE
Effective January 1, 1993, Pinnacle West adopted the provisions of SFAS No. 109, "Accounting for Income Taxes," which requires the use of the liability method of accounting for income taxes. The cumulative effect on prior years of this change in accounting principle resulted in an increase to net income of $19.3 million, due primarily to the recognition of deferred tax benefits relating to state NOL carryforwards of Pinnacle West. As a result of adopting SFAS No. 109, APS recorded additional deferred income taxes related to the equity comoponent of AFUDC; the debt component of AFUDC net-of-tax; and other temporary differences for which deferred income taxes had not been provided. Deferred tax balances were also adjusted for changes in tax rates. The adoption of SFAS No.109 increased deferred income tax liabilities by $585.3 million at December 31, 1993. Historically, the FERC and the ACC have allowed revenues sufficient to pay for these deferred tax liabilities and, in accordance with SFAS No. 109, a regulatory asset was established in a corresponding amount.
The components of income tax expense (benefit) from continuing operations are as follows:
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Income tax expense (benefit) differed from the amount computed by multiplying income from continuing operations before income taxes by the statutory federal income tax rate due to the following:
The components of the net deferred income tax liability at December 31, 1993, were as follows:
At December 31, 1993, Pinnacle West had federal NOL carryforwards of approximately $304 million which may be used through 2005 and state NOL carryforwards of approximately $218 million which expire in 1994 through 1996. Pinnacle West also had ITC carryforwards of approximately $41 million which expire in 2000 through 2005.
See Note 2 for tax benefits recorded in connection with discontinued operations.
5. LINES OF CREDIT
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
APS had committed lines of credit with various banks totalling $302 million at December 31, 1993 and 1992 which were available either to support the issuance of commercial paper or to be used for bank borrowings. The commitment fees on these lines were 0.1875% per annum through April 29, 1992 and 0.25% thereafter through December 31, 1993. APS had commercial paper borrowings outstanding of $148 million at December 31, 1993 and bank borrowings of $130 million at December 31, 1992.
In 1992, APS also had a $70 million letter of credit commercial paper program. Under this program, which expired in November 1993, APS had $65 million of borrowings outstanding at December 31, 1992. The commitment fees for this program were 0.30% per year.
By Arizona statute, APS' short-term borrowings cannot exceed 7% of its total capitalization without the consent of the ACC.
Pinnacle West had a liquidity facility of $40 million at December 31, 1993 and $50 million at December 31, 1992. The facility is available for payments of principal and interest on Pinnacle West's outstanding debt with a maximum of $20 million for principal payments. Any borrowings on this facility would be secured by the APS common stock owned by Pinnacle West and would bear interest, at Pinnacle West's option, at rates based on the prime rate or on LIBOR. Pinnacle West pays a 0.3125% commitment fee on the facility based on existing long-term credit ratings. There were no borrowings outstanding under the liquidity facility at December 31, 1993 or 1992.
6. LONG-TERM DEBT
In January 1990, Pinnacle West restructured the majority of its long-term debt. Pinnacle West granted the affected lenders a security interest in the outstanding common stock of APS and agreed not to incur new debt except to reduce, refinance or prepay existing debt. Pinnacle Wests ability to pay dividends is dependent upon the satisfaction of specified interest coverage ratios. Additionally, cumulative dividend payments for the period April 1, 1990 through any dividend declaration date are limited to 50% of cumulative consolidated net income (as defined) for the same period. As of December 31, 1993, Pinnacle West could have declared dividends of approximately $241 million based on this formula. Pinnacle West's aggregate investments in its existing subsidiaries (excluding APS) and new investments are generally limited to $15 million and $20 million, respectively, until the lenders are repaid. Pinnacle West must maintain certain interest coverage ratios and meet certain funded debt tests. Additionally, Pinnacle West would be required to use the net cash proceeds from the sale of SunCor or El Dorado or substantially all of their assets to repay debt. The following table presents long-term debt outstanding as of December 31, 1993 and 1992.
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Aggregate annual principal payments due on total long-term debt and for sinking fund requirements through 1998 are as follows: 1994, $78,841,000; 1995, $82,625,000; 1996, $43,858,000; 1997, $231,543,000; and 1998, $110,297,000. See Note 7 for redemption and sinking fund requirements of redeemable preferred stock of APS.
Substantially all utility plant other than nuclear fuel, transportation equipment and the combined cycle plant, is subject to the lien of the first mortgage bonds. The first mortgage bond indenture includes provisions which would restrict the payment of dividends on APS common stock under certain conditions which did not exist at December 31, 1993.
Pinnacle West and its subsidiaries incurred interest expense of $264,306,000, $286,347,000 and $333,923,000 in 1993, 1992 and 1991, of which $1,840,000, $1,389,000 and $1,194,000 was capitalized in each year, respectively.
APS had approximately $370 million of variable-rate long-term debt outstanding at December 31, 1993. Changes in interest rates would affect the costs associated with this debt.
7. PREFERRED STOCK OF APS
Non-redeemable preferred stock is not redeemable except at the option of APS. Redeemable preferred stock is redeemable through sinking fund obligations in addition to being callable by APS. The balances at December 31, 1993 and 1992, of preferred stock of APS are shown below:
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
If there were to be any arrearage in dividends on any of its preferred stock or in the sinking fund requirements applicable to any of its redeemable preferred stock, APS could not pay dividends on its common stock or acquire any shares thereof for consideration. The combined aggregate amount of preferred stock redemption requirements for the next five years are: 1994, $65,775,000; 1995, $13,525,000; 1996, $13,525,000; 1997, $13,525,000; and 1998, $13,525,000.
Redeemable preferred stock transactions of APS during each of the three years in the period ended December 31, 1993, are as follows:
NUMBER OF PAR VALUE SHARES AMOUNT ---------- --------- (THOUSANDS OF DOLLARS) Balance, December 31, 1990............................. 1,924,532 $192,453 Issuance $10.00 Series U...................................... 500,000 50,000 Retirements $10.00 Series H...................................... (16,000) (1,600) $8.80 Series K....................................... (40,275) (4,027) $12.90 Series N...................................... (24,975) (2,498) $11.50 Series R...................................... (70,500) (7,050) ---------- --------- Balance, December 31, 1991............................. 2,272,782 227,278 Issuance $7.875 Series V...................................... 250,000 25,000 Retirements $10.00 Series H...................................... (8,677) (868) $8.80 Series K....................................... (4,725) (472) $12.90 Series N...................................... (213,280) (21,328) $11.50 Series R...................................... (39,750) (3,975) ---------- --------- Balance, December 31, 1992............................. 2,256,350 225,635 Retirements $8.80 Series K....................................... (45,000) (4,500) $11.50 Series R...................................... (35,250) (3,525) $8.48 Series S....................................... (200,000) (20,000) ---------- --------- Balance, December 31, 1993............................. 1,976,100 $ 197,610 ========== =========
8. COMMON STOCK
Pinnacle West's common stock issued during each of the three years in the period ended December 31, 1993, is as follows:
NUMBER OF PAR VALUE SHARES AMOUNT ---------- ----------- Balance, December 31, 1990........................... 86,873,174 $1,646,570 Common stock issued................................ 136,800 319 ---------- ----------- Balance, December 31, 1991........................... 87,009,974 1,646,889 Common stock issued................................ 151,898 (117) ---------- ----------- Balance, December 31, 1992........................... 87,161,872 1,646,772 Common stock issued................................ 261,945 (3,989) ---------- ----------- Balance, December 31, 1993........................... 87,423,817 $1,642,783 ========== ===========
- ---------- (a) Including premiums and expenses of preferred stock issues of APS.
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
The Pinnacle West Stock Purchase and Dividend Reinvestment Plan provides that any participant may purchase shares of Pinnacle West common stock directly from Pinnacle West.
Both Pinnacle West and APS have employee savings plans under which contributions by participating employees and contributions by employers could involve the issuance of new shares of Pinnacle West common stock. Contributions made by Pinnacle West and APS to their respective employee retirement plans may also involve one or more such issuances of common stock.
However, Pinnacle West plans to continue making market purchases of its outstanding stock to meet its needs related to the Stock Purchase and Dividend Reinvestment Plan, the employee savings plans and the employee retirement plans.
Under the Pinnacle West Stock Option and Incentive Plan, non-qualified stock options (NQSOs), incentive stock options (ISOs) and restricted stock awards may be granted to officers and key employees of Pinnacle West and subsidiaries up to an aggregate of 3 million shares of Pinnacle West common stock. The plan also provides for the granting of stock appreciation rights, performance shares, dividend equivalents or any combination thereof. Another plan provides for the granting of NQSOs to Pinnacle Wests directors up to an aggregate of 500,000 shares of stock. As of December 31, 1993, approximately 333,000 restricted shares, 1,789,000 NQSOs, 10,000 ISOs and 30,000 dividend equivalent shares were outstanding under the plans.
9. PENSION PLANS AND OTHER BENEFITS
Pension plans
Pinnacle West and its subsidiaries have defined benefit pension plans covering substantially all employees. Benefits are based on years of service and compensation utilizing a final average pay plan benefit formula. The plans are funded on a current basis to the extent deductible under existing tax regulations. Plan assets consist primarily of domestic and international common stocks and bonds and real estate. Pension cost, including administrative cost, for 1993, 1992 and 1991 was approximately $14,267,000, $14,384,000 and $10,913,000, respectively, of which approximately $6,833,000, $4,279,000 and $5,262,000, respectively, was charged to expense; the remainder was either capitalized as a component of construction cost or billed to other owners of facilities for which APS is operating agent.
The components of net periodic pension costs are as follows:
1993 1992 1991 --------- -------- -------- (THOUSANDS OF DOLLARS) Service cost -- benefits earned during the period....................................... $17,051 $17,227 $14,831 Interest cost on projected benefit obligation.. 35,046 33,633 31,216 Return on plan assets.......................... (52,026) (23,225) (65,262) Net amortization and deferral.................. 13,547 (15,097) 28,924 --------- -------- -------- Net consolidated periodic pension cost......... $13,618 $12,538 $ 9,709 ========= ======== ========
The discount rate used in determining the actuarial present value of the projected benefit obligation was 7.50% in 1993 and 8.25% in 1992. The rate of increase in future compensation levels used was 5.0% in 1993 and 1992. The expected long-term rate of return on assets was 9.5% in 1993 and 1992; in 1994, the company will assume a 9% rate of return.
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
A reconciliation of the funded status of the plan to the amounts recognized in the balance sheet is presented below:
1993 1992 --------- --------- (THOUSANDS OF DOLLARS) Plan assets at fair value............................... $ 421,563 $ 391,827 --------- --------- Less actuarial present value of benefit obligation, including vested benefits of $350,812 and $288,456 in 1993 and 1992, respectively........................... 375,800 309,607 Effect of projected future compensation increases....... 128,797 106,218 --------- --------- Total projected benefit obligation...................... 504,597 415,825 --------- --------- Plan assets less than projected benefit obligation...... (83,034) (23,998) Plus: Unrecognized net loss from past experience different from that assumed........................... 51,551 8,097 Unrecognized prior service cost................... 14,866 15,893 Unrecognized net transition asset................. (39,371) (42,597) --------- --------- Accrued pension liability............................... $ (55,988) $ (42,605) ========= =========
In addition to the defined benefit pension plans described above, Pinnacle West and its subsidiaries also sponsor qualified defined contribution plans. Collectively, these plans cover substantially all employees. The plans provide for employee contributions and partial employer matching contributions after certain eligibility requirements are met. The cost of these plans for 1993, 1992 and 1991 was $6,391,000, $5,404,000 and $2,756,000, of which $3,114,000, $2,607,000 and $1,392,000 was charged to expense.
Postretirement Plans
Pinnacle West and its subsidiaries provide medical and life insurance benefits to their retired employees. Employees may become eligible for these retirement benefits based on years of service and age. The retiree medical insurance plan is contributory; the retiree life insurance plan is noncontributory. In accordance with the governing plan documents, the companies retain the right to change or eliminate these benefits.
During 1993, Pinnacle West adopted SFAS No. 106, "Employers Accounting for Postretirement Benefits Other Than Pensions," which requires that the cost of postretirement benefits be accrued during the years that the employees render service. Prior to 1993, the costs of retiree benefits were recognized as expense when claims were paid. This change had the effect of increasing 1993 retiree benefit costs from approximately $6 million to $35 million; the amount charged to expense increased from approximately $2 million to $17 million for an increase of $15 million including the amortization (over 20 years) of the initial postretirement benefit obligation estimated at January 1, 1993 to be $184 million. Funding is based upon actuarially determined contributions that take tax consequences into account.
The components of the estimated postretirement benefit costs for 1993 are:
(THOUSANDS OF DOLLARS) Service cost -- benefits earned during the period.... $ 9,710 Interest cost on accumulated benefit obligation...... 15,755 Net amortization and deferral........................ 9,212 ------- Net consolidated periodic postretirement benefit cost $34,677 =======
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
A reconciliation of the funded status of the plan to the amounts recognized in the balance sheet for 1993 is presented below:
Plan assets at fair value, funded at December 31, 1993.. $ 28,154 ---------- Less accumulated postretirement benefit obligation: Retirees............................................ 49,493 Fully eligible plan participants.................... 13,671 Other active plan participants...................... 138,364 ---------- Total accumulated postretirement obligation............. 201,528 ---------- Plan assets less than accumulated benefit obligation.... (173,374) Plus: Unrecognized transition obligation................ 175,023 Unrecognized net gain from past experience different from that assumed and from from changes in assumptions...................... (2,089) ---------- Accrued postretirement liability included in other deferred credits...................................... $ (440) ========== Principal actuarial assumptions used were: Discount rate......................................... 7.50% Initial health care cost trend rate under age 65...... 12.00% Initial health care cost trend rate -- age 65 and over 9.00% Ultimate health care cost trend rate (reached in the year 2003).......................... 5.50% Annual salary increases for life insurance obligation. 5.00%
Assuming a one percent increase in the health care cost trend rate, the Company's 1993 cost of postretirement benefits other than pensions would increase by $6.9 million and the accumulated benefit obligation as of December 31, 1993 would increase by $40.8 million.
In 1993, Pinnacle West adopted SFAS No. 112, "Employers Accounting for Postemployment Benefits." The new standard requires a change from a cash method to an accrual method in accounting for benefits (such as long-term disability) provided to former or inactive employees after employment but before retirement. The adoption of this new standard resulted in an increase in 1993 postemployment benefit costs of approximately $2 million.
10. SUPPLEMENTAL INCOME STATEMENT INFORMATION
Other taxes charged to operations during each of the three years in the period ended December 31, 1993 are as follows:
1993 1992 1991 --------- -------- -------- (THOUSANDS OF DOLLARS) Ad valorem..................................... $124,630 $119,173 $121,936 Sales.......................................... 84,901 83,185 80,815 Other.......................................... 12,814 14,705 12,790 --------- -------- -------- Total other taxes.............................. $222,345 $217,063 $215,541 ========= ======== ========
11. LEASES
In 1986, APS entered into sale and leaseback transactions under which it sold approximately 42% of its share of Palo Verde Unit 2. The gain of approximately $140,220,000 has been deferred and is being amortized to expense over the original lease term. The leases are being accounted for as operating leases. The amounts paid each year approximate $40,134,000 through December 1999; $46,285,000 through December 2000; and $48,982,000 through December 2015. Options to renew the leases for two additional years and to purchase the property at fair market value at the end of the lease terms are also included. Lease expense for 1993, 1992 and 1991 was $41,750,000, $45,838,000 and $45,633,000, respectively.
APS has a capital lease on a combined cycle plant which it sold and leased back. The lease requires semiannual payments of $2,582,000 through June 2001, and includes renewal and purchase options based on fair market value. This plant is included in electric plant in service at its original cost of $54,405,000; accumulated depreciation at December 31, 1993 was $37,315,000.
In addition, Pinnacle West and its subsidiaries lease certain land, buildings, equipment and miscellaneous other items through operating rental agreements with varying terms, provisions and expiration dates. Rent expense for 1993, 1992 and 1991 was approximately $21,535,000, $26,104,000 and $28,185,000, respectively. Annual future minimum rental commitments, excluding the Palo Verde and combined cycle leases, through 1998 are as follows: 1994, $22,879,000; 1995, $17,183,000; 1996, $14,146,000; 1997, $14,120,000; and 1998, $14,126,000. Total rental commitments after 1998 are estimated at $198 million.
12. JOINTLY-OWNED FACILITIES
At December 31, 1993, APS owned interests in the following jointly-owned electric generating and transmission facilities. APS' share of related operating and maintenance expenses is included in utility operations and maintenance.
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
13. COMMITMENTS AND CONTINGENCIES
Litigation
Pinnacle West and its subsidiaries are parties to various claims, legal actions and complaints arising out of the normal course of business. Various claims have been asserted against Pinnacle West and against present and former directors of Pinnacle West and MeraBank. A settlement agreement that would resolve the preponderance of these claims has been approved by the court. An appeal of the settlement by two non-settling individuals is pending. In the opinion of management, the ultimate resolution of these claims will not have a material adverse effect on the operations or financial position of Pinnacle West.
Palo Verde Tube Cracks
Tube cracking in the Palo Verde steam generators adversely affected operations in 1993, and will continue to do so in 1994 and probably into 1995, because of the cost of replacement power and maintenance expense associated with unit outages and corrective actions required to deal with the issue.
The operation of Palo Verde Unit 2 has been particularly affected by this issue. APS has encountered axial tube cracking in the upper regions of the two steam generators in Unit 2. This form of tube degradation is uncommon in the industry and, in March 1993, led to a tube rupture and an outage of the unit that extended to September 1993, during which the unit was refueled. Unit 2 is currently completing a mid-cycle inspection outage which revealed further tube degradation. Unit 2 will have another mid-cycle inspection outage later in 1994.
The steam generators of Units 1 and 3 were inspected late in 1993, but did not show signs of axial cracking in their upper regions. All three units have, however, experienced cracking in the bottom of the steam generators of the types which are common in the industry.
Although its analysis is not yet completed, APS believes that the axial cracking in Unit 2 is due to deposits on the tubes and to the relatively high temperatures at which all three units are now designed to operate. APS also believes that it can retard further tube degradation to acceptable levels by remedial actions which include chemically cleaning the generators and performing analyses and adjustments that will allow the units to be operated at lower temperatures without appreciably reducing their output. The temperature analyses should be concluded within the next several months. In the meantime, the lower temperatures will be achieved by operating the units at less than full power (86%).
Chemical cleaning was performed during Unit 2's current mid-cycle outage, and will be performed in the next refueling outage of Unit 3 (which will begin shortly) and of Unit 1 (which is scheduled for March 1995). APS has concluded that Unit 1 can be safely operated until the 1995 outage and has submitted its supporting analysis to the Nuclear Regulatory Commission, but a mid-cycle inspection later in 1994 is possible.
As a result of these corrective actions, all three units should be returned to full power by mid-1995, and one or more of the units could be returned to full power during 1994. So long as the three units are involved in mid-cycle outages and are operated at 86%, APS will incur additional fuel and purchased power costs averaging approximately $2 million per month (before income taxes).
Because of schedule changes associated with the tube issues and other circumstances, it now appears that all three units will be down for refueling outages at various times during 1995.
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
When significant cracks are detected during any outage, the affected tubes are taken out of service by plugging. That has occurred in a number of tubes in Unit 2, which is by far the most affected by cracking and plugging. APS expects that this will slow considerably because of the foregoing remedial actions and that, while it may ultimately reach some limit on plugging, it can operate the present steam generators over a number of years.
Construction Program
Total construction expenditures in 1994 are estimated at $312 million, excluding capitalized property taxes and capitalized interest.
Fuel and Purchased Power Commitments
APS is a party to various fuel and purchased power contracts with terms expiring from 1994 through 2020. APS estimates its 1994 contract requirements at approximately $136 million. However, this amount may vary significantly pursuant to certain provisions in such contracts which permit APS to decrease its required purchases under certain circumstances.
Nuclear Insurance
The Palo Verde participants have insurance for public liability 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. The maximum assessment per reactor under the retrospective rating program for each nuclear incident is approximately $79 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 $69 million, with an annual payment limitation of $8.73 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.
El Paso Electric Company Bankruptcy
The other joint owners in the Palo Verde and Four Corners facilities (see Note 12) include El Paso Electric Company, which currently is operating under Chapter 11 of the Bankruptcy Code. A plan whereby El Paso would become a wholly-owned subsidiary of Central and South West Corporation would resolve certain issues to which APS could be exposed by the bankruptcy, including El Paso allegations regarding the 1989-1990 Palo Verde outages. The plan has been confirmed by the bankruptcy court, but cannot become fully effective until several additional or related approvals are obtained. If they are not obtained, the plan could be withdrawn or terminate, thereby reintroducing the APS exposures.
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
14. SELECTED QUARTERLY FINANCIAL DATA (UNAUDITED)
Consolidated quarterly financial information for 1993 and 1992 is as follows:
PINNACLE WEST CAPITAL CORPORATION NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
15. FAIR VALUE OF FINANCIAL INSTRUMENTS
Pinnacle West estimates that the carrying amounts of its cash equivalents and commercial paper are reasonable estimates of their fair values at December 31, 1993 and 1992 due to their short maturities. The December 31, 1993 and 1992 fair values of debt and equity investments, determined by using quoted market values or by discounting cash flows at rates equal to the Company's costs of capital, approximate their carrying amounts.
It was not practicable to estimate the fair values of several investments in joint ventures and untraded equity securities because costs to do so would be excessive. The carrying value of these investments totalled $45.6 million and $63.6 million at year-end 1993 and 1992, respectively.
On December 31, 1993, the carrying amount of long-term debt liabilities (excluding $30 million of capital lease obligations) was $2.682 billion and its estimated fair value was approximately $2.911 billion. On December 31, 1992, the carrying amount of long-term debt (excluding $32 million of capital lease obligations was $2.848 billion and its estimated fair value was approximately $3.020 billion. The fair value estimates were determined by independent sources using quoted market rates where available. Where market prices were not available, the fair values were estimated by discounting future cash flows using rates available for debt of similar terms and remaining maturities. The carrying amounts of long-term debt bearing variable interest rates approximate their fair values at December 31, 1993 and 1992.
PINNACLE WEST CAPITAL CORPORATION
SCHEDULE IX -- SHORT-TERM BORROWINGS
Column A Column B Column C (b) Column D Column E (a) Column F (b)
Weighted Weighted average Maximum Average average Category of Balance interest amount amount interest aggregate at end rate outstanding outstanding rate short-term of at end of during the during the during the borrowings period period period period period ---------- -------- ------------ ----------- ------------ ------------ (Dollars in Thousands)
YEAR ENDED DECEMBER 31, 1993 Bank Borrowings $ -- -- % $130,000 $63,616 3.97% Commercial Paper 148,000 3.48 148,000 23,049 3.36
YEAR ENDED DECEMBER 31, 1992 Bank Borrowings $130,000 4.28% $175,000 $ 9,372 5.25% Commercial Paper 65,000 3.73 70,000 12,682 3.75
YEAR ENDED DECEMBER 31, 1991 Bank Borrowings $ -- -- % $100,000 $26,973 7.44% Commercial Paper -- -- 70,000 24,077 6.74 - ---------- (a) Average daily balance during the period.
(b) Total applicable interest in the period divided by average daily balance.
ITEM 9.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.
PART III
ITEM 10.
ITEM 10. DIRECTORS AND EXECUTIVE OFFICERS OF THE REGISTRANT
Reference is hereby made to "Election of Directors" in the Company's Proxy Statement relating to the annual meeting of shareholders to be held on May 19, 1994 (the "1994 Proxy Statement") and to the Supplemental Item -- "Executive Officers of the Company" in Part I of this report.
ITEM 11.
ITEM 11. EXECUTIVE COMPENSATION
Reference is hereby made to the last two paragraphs under the heading "The Board and its Committees," and to "Summary Compensation Table," "Option Grants 1993," "Option Exercises and Year-End Values," and "Executive Benefit Plans" in the 1994 Proxy Statement.
ITEM 12.
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT
Reference is hereby made to "Certain Securities Ownership" in the 1994 Proxy Statement.
ITEM 13.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
None.
PART IV
ITEM 14.
ITEM 14. EXHIBITS, FINANCIAL STATEMENTS, FINANCIAL STATEMENT SCHEDULES, AND REPORTS ON FORM 8-K
FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES
See the Index to Financial Statements and Financial Statement Schedules in Part II, Item 8.
EXHIBITS FILED
EXHIBIT NO. DESCRIPTION - ----------- -----------
10.1 -- Summary of the Pinnacle West Capital Corporation 1994 Bonus Plan
22 -- Subsidiaries of the Company
23.1 -- Consent of Deloitte & Touche
In addition to those Exhibits shown above, the Company hereby incorporates the following Exhibits pursuant to Exchange Act Rule 12b-32 and Regulation (S) 201.24 by reference to the filings set forth below:
REPORTS ON FORM 8-K
During the quarter ended December 31, 1993, and the period ended March 30, 1994, the Company filed the following Reports on Form 8-K:
Report dated December 15, 1993, regarding (i) inspections of the steam generators of the Palo Verde units and related issues and (ii) APS' settlement agreement with a former contract employee.
Report dated January 24, 1994 regarding the settlement and dismissal of certain lawsuits involving the Company, one of the lawsuits being partially dismissed.
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
PINNACLE WEST CAPITAL CORPORATION (Registrant)
Date: March 30, 1994 RICHARD SNELL ---------------------------------------------------- (Richard Snell, Chairman of the Board of Directors, President and Chief Executive Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.
Signature Title Date --------- ----- ----
RICHARD SNELL Principal Executive March 30, 1994 - ---------------------------------------- Officer and Director (Richard Snell, Chairman of the Board of Directors, President and Chief Executive Officer)
H. B. SARGENT Principal Financial March 30, 1994 - ---------------------------------------- Officer, Principal (H. B. Sargent, Executive Vice President Accounting Officer and Chief Financial Officer) and Director
O. MARK DE MICHELE Director March 30, 1994 - ---------------------------------------- (O. Mark De Michele)
PAMELA GRANT Director March 30, 1994 - ---------------------------------------- (Pamela Grant)
ROY A. HERBERGER, JR. Director March 30, 1994 - ---------------------------------------- (Roy A. Herberger, Jr.)
MARTHA O. HESSE Director March 30, 1994 - ---------------------------------------- (Martha O. Hesse)
WILLIAM S. JAMIESON, JR. Director March 30, 1994 - ---------------------------------------- (William S. Jamieson, Jr.)
JOHN R. NORTON, III Director March 30, 1994 - ---------------------------------------- (John R. Norton, III)
DONALD N. SOLDWEDEL Director March 30, 1994 - ---------------------------------------- (Donald N. Soldwedel)
DOUGLAS J. WALL Director March 30, 1994 - ---------------------------------------- (Douglas J. Wall)
APPENDIX
In accordance with Item 304 of Regulation S-T of the Securities Exchange Act of 1934, APS' Service Territory map contained in this Form 10-K is a map of the state of Arizona showing APS' service area, the location of its major power plants and principal transmission lines, and the location of transmission lines operated by APS for others. The major power plants shown on such map are the Navajo Generating Station located in Coconino County, Arizona; the Four Corners Power Plant located near Farmington, New Mexico; the Cholla Power Plant, located in Navajo County, Arizona; the Yucca Power Plant, located near Yuma, Arizona; and the Palo Verde Nuclear Generating Station, located about 55 miles west of Phoenix, Arizona (each of which plants is reflected on such map as being jointly owned with other utilities), as well as the Ocotillo Power Plant and West Phoenix Power Plant, each located near Phoenix, Arizona, and the Saguaro Power Plant, located near Tucson, Arizona. APS' major transmission lines shown on such map are reflected as running between the power plants named above and certain major cities in the state of Arizona. The transmission lines operated for others shown on such map are reflected as running from the Four Corners Plant through a portion of northern Arizona to the California border.
COMMISSION FILE NUMBER 1-8962 - ------------------------------------------------------------------------------ - ------------------------------------------------------------------------------
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, D.C. 20549 --------------
EXHIBITS TO
FORM 10-K
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(D) OF
THE SECURITIES EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED DECEMBER 31, 1993 --------------
PINNACLE WEST CAPITAL CORPORATION
(EXACT NAME OF REGISTRANT AS SPECIFIED IN CHARTER) - ------------------------------------------------------------------------------ - ------------------------------------------------------------------------------
INDEX TO EXHIBITS
Exhibit No. Description - ----------- ----------- 10.1 -- Summary of the Pinnacle West Capital Corporation 1994 Bonus Plan
22 -- Subsidiaries of the Company
23.1 -- Consent of Deloitte & Touche