**EXHIBIT 99.32**
**APS RISK FACTORS**
**(Report on Form 10-K for the fiscal year ended December 31, 2004)**
     Set forth below and in other documents we file with the Securities and Exchange Commission arerisks and uncertainties that could affect our financial results.
     **We cannot predict the outcome of our general rate case pending before the Arizona CorporationCommission (the “ACC”).**
     On June 27, 2003, we filed a request with the ACC to increase annual retail electricityrevenues by approximately $175.1 million, or 9.8%, effective July 1, 2004. On August 18, 2004, asubstantial majority of the parties to the rate case, including us, the ACC staff, the ResidentialUtility Consumer Office, other customer groups, and merchant power plant intervenors entered intoan agreement that proposes terms under which the rate case would be settled (the “2004 SettlementAgreement”). The 2004 Settlement Agreement is subject to ACC approval. Key financial components ofthe 2004 Settlement Agreement are as follows:
 •  We would receive an annual retail rate increase of approximately $75.5 million, or 4.21%.The increase would consist of an increase in base rates of approximately 3.77% and anincrease of approximately 0.44% for recovery over five years of the past costs of ourcompliance with the ACC’s retail electric competition rules (the “Rules”).  •  We would acquire from Pinnacle West Energy Corporation (“Pinnacle West Energy”) RedhawkCombined Cycle Units 1 and 2, West Phoenix Combined Cycle Units 4 and 5, and SaguaroCombustion Turbine Unit 3 (collectively, the “DedicatedAssets”), with a net carrying value of approximately$850 million, and rate base the DedicatedAssets at a rate base value of $700 million, which would result in a regulatory rate basedisallowance of $148 million. As a result, for financial reporting purposes, we wouldrecognize a one-time, after-tax net plant write-off of approximately $88 million in theperiod when the plant transfer to us is completed, and would reduce annual depreciationexpense by approximately $5 million.  •  To bridge the time between the effective date of the rate increase and the actual date theDedicated Assets transfer, we and Pinnacle West Energy would enter into a cost-basedpurchase power agreement (the “Bridge PPA”), which would be based on the value of theDedicated Assets described in the previous bullet point. The Bridge PPA would remain ineffect until the Federal Energy Regulatory Commission (the “FERC”) approves the transfer ofthe Dedicated Assets to us and the transfer is completed.  •  If the FERC were to issue an order denying our request to acquire the Dedicated Assets, theBridge PPA would become a 30-year purchased power agreement, with prices reflectingcost-of-service as if we had acquired and rate-based the Dedicated Assets at the valuedescribed above.  •  If the FERC were to issue an order (a) approving our request to transfer the DedicatedAssets at a value materially less than $700 million, (b) approving the transfer of fewerthan all of the Dedicated Assets, or (c) that was materially inconsistent with the 2004Settlement Agreement, we would file an appropriate application with the ACC so that ratescould be adjusted. In these circumstances, the Bridge PPA would continue at least until theconclusion of the subsequent proceeding to consider any appropriate adjustment to our rates.  •  A power supply adjuster (“PSA”) would provide for the recovery of fuel and purchased powercosts, subject to specified parameters and procedures.  •  We would not restore and recover in rates the $234 million write-off recorded in 1999 as aresult of a 1999 settlement agreement approved by the ACC related to the implementation ofretail electric competition in Arizona (the “1999 Settlement Agreement”).  •  We would adopt longer service lives than originally requested for certain depreciable assets.
     On February 28, 2005, the administrative law judge in the general rate case issued arecommended order. The recommended order proposes ACC approval of the 2004 Settlement Agreementwith two changes related to the
 

 

PSA. First, the amount of gas costs that we could recover underthe annual PSA would be limited to $500 million per year. Second, although the 2004 SettlementAgreement provides that the PSA would remain in effect for a minimum five-year period, under therecommended order the ACC would be able to eliminate the PSA at any time, if appropriate, if wefile a rate case before the expiration of the five-year period or if we do not comply with theterms of the PSA. If we exceed the gas costs that could be recoverable under the PSA or if the ACCeliminates the PSA, we would retain the right to file a rate case to reset our base rates. Wecannot predict the outcome of this matter.
     **The procurement of wholesale power by us without the ability to adjust retail rates could havean adverse impact on our business and financial results.**
     Although the Rules allow retail customers to have access to competitive providers of energyand energy services, under the Rules, we are the “provider of last resort” for standard-offer,full-service customers under rates that have been approved by the ACC. In the event of shortfallsof electricity due to unforeseen increases in load demand or generation or transmission outages, wemay need to purchase additional supplemental power in the wholesale spot market. At various times,prices in the spot wholesale market have significantly exceeded the amount included in our currentretail rates. There can be no assurance that we would be able to fully recover the costs of thispower. Although the proposed settlement of our general rate case would, among other things, allowus to recover purchased power costs, there can be no assurance that the 2004 Settlement Agreementwill be approved by the ACC as proposed.
     **Deregulation or restructuring of the electric industry may result in increased competition,which could have a significant adverse impact on our business and our financial results.**
     Retail competition could have a significant adverse financial impact on us due to animpairment of assets, a loss of retail customers, lower profit margins or increased costs ofcapital. Under the Rules, as modified by the 1999 Settlement Agreement, we were required totransfer all of our competitive electric assets and services to an unaffiliated party or parties orto a separate corporate affiliate or affiliates no later than December 31, 2002. To satisfy thisrequirement, we had planned to transfer our generation assets to Pinnacle West Energy. Pursuant toan ACC order dated September 10, 2002, the ACC unilaterally modified the 1999 Settlement Agreementand directed us to cancel any plans to divest interests in any of our generating assets. The ACCfurther established a requirement that we solicit bids for certain estimated amounts of capacityand energy for periods beginning July 1, 2003. Pinnacle West Energy bid on and entered intocontracts to supply most of our requirements in the summer months through September 2006. Inaddition, as discussed above, a proposed settlement of our general rate case would result inPinnacle West Energy transferring a significant amount of generation assets to us. These regulatorydevelopments and legal challenges to the Rules have raised considerable uncertainty about thestatus and pace of retail electric competition and of electric restructuring in Arizona. Althoughsome very limited retail competition existed in our service area in 1999 and 2000, there arecurrently no active retail competitors offering unbundled energy or other utility services to ourcustomers. As a result, we cannot predict when, and the extent to which, additional competitorswill re-enter our service territory.
     As a result of changes in federal law and regulatory policy, competition in the wholesaleelectricity market has greatly increased due to a greater participation by traditional electricitysuppliers, non-utility generators, independent power producers, and wholesale power marketers andbrokers. This increased competition could affect our load forecasts, plans for power supply andwholesale energy sales and related revenues. As a result of the changing regulatory environment andthe relatively low barriers to entry, we expect wholesale competition to increase. As competitioncontinues to increase, our financial position and results of operations could be adverselyaffected.
     **We are subject to complex government regulation that may have a negative impact on ourbusiness and our results of operations.**
     We are subject to governmental regulation that may have a negative impact on our business andresults of operations. We are a “subsidiary company” of a “holding company” within the meaning ofthe Public Utility Holding Company Act of 1935 (“PUHCA”); however, we are exempt from theprovisions of PUHCA (except Section 9(a)(2) thereof) by virtue of the filing of an annual exemptionstatement with the Securities and Exchange Commission (the “SEC”) by our parent company, PinnacleWest Capital Corporation (“Pinnacle West”).
     We are subject to comprehensive regulation by several federal, state and local regulatoryagencies, which significantly influence our operating environment and may affect our ability torecover costs from utility customers. We are required to have numerous permits, approvals andcertificates from the agencies that regulate our business.
 

 

The FERC, the Nuclear RegulatoryCommission (“NRC”), the Environmental Protection Agency (“EPA”), and the ACC regulate many aspectsof our utility operations, including siting and construction of facilities, customer service andthe rates that we can charge customers. We believe the necessary permits, approvals andcertificates have been obtained for our existing operations. However, changes in regulations or theimposition of additional regulations could have an adverse impact on our results of operations. Weare also unable to predict the impact on our business and operating results from pending or futureregulatory activities of any of these agencies.
     **We are subject to numerous environmental laws and regulations that may increase our cost ofoperations, impact our business plans, or expose us to environmental liabilities.**
     We are subject to numerous environmental laws and regulations affecting many aspects of ourpresent and future operations, including air emissions, water quality, wastewater discharges, solidwaste, and hazardous waste. These laws and regulations can result in increased capital, operating,and other costs, particularly with regard to enforcement efforts focused on power plant emissionsobligations. These laws and regulations generally require us to obtain and comply with a widevariety of environmental licenses, permits, inspections and other approvals. Both public officialsand private individuals may seek to enforce applicable environmental laws and regulations. Wecannot predict the outcome (financial or operational) of any related litigation that may arise.
     In addition, we may be a responsible party for environmental clean up at sites identified by aregulatory body. We cannot predict with certainty the amount and timing of all future expendituresrelated to environmental matters because of the difficulty of estimating clean-up costs. There isalso uncertainty in quantifying liabilities under environmental laws that impose joint and severalliability on all potentially responsible parties.
     We cannot be sure that existing environmental regulations will not be revised or that newregulations seeking to protect the environment will not be adopted or become applicable to us.Revised or additional regulations that result in increased compliance costs or additional operatingrestrictions, particularly if those costs are not fully recoverable from our customers, could havea material adverse effect on our results of operations.
     **There are inherent risks in the operation of nuclear facilities, such as environmental, healthand financial risks and the risk of terrorist attack.**
     We have an ownership interest in and operate, on behalf of a group of owners, the Palo VerdeNuclear Generating Station (“Palo Verde”), which is the largest nuclear electric generatingfacility in the United States. Palo Verde is subject to environmental, health and financial riskssuch as the ability to dispose of spent nuclear fuel, the ability to maintain adequate reserves fordecommissioning, potential liabilities arising out of the operation of these facilities, and thecosts of securing the facilities against possible terrorist attacks and unscheduled outages due toequipment and other problems. We maintain nuclear decommissioning trust funds and externalinsurance coverage to minimize our financial exposure to some of these risks; however, it ispossible that damages could exceed the amount of insurance coverage.
     The NRC has broad authority under federal law to impose licensing and safety-relatedrequirements for the operation of nuclear generation facilities. In the event of noncompliance, theNRC has the authority to impose fines or shut down a unit, or both, depending upon its assessmentof the severity of the situation, until compliance is achieved. In addition, although we have noreason to anticipate a serious nuclear incident at Palo Verde, if an incident did occur, it couldmaterially and adversely affect our results of operations or financial condition. A major incidentat a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operationor licensing of any domestic nuclear unit.
     The operation of Palo Verde requires licenses that need to be periodically renewed and/orextended. We do not anticipate any problems renewing these licenses. However, as a result ofpotential terrorist threats and increased public scrutiny of utilities, the licensing process couldresult in increased licensing or compliance costs that are difficult or impossible to predict.
     **The uncertain outcome regarding the creation of regional transmission organizations, or RTOs,and implementation of the FERC’s standard market design may materially impact our operations, cashflows or financial position.**
     In a December 1999 order, the FERC established characteristics and functions that must be metby utilities in forming and operating RTOs. The characteristics for an acceptable RTO includeindependence from market participants, operational control over a region large enough to supportefficient and nondiscriminatory markets and exclusive authority to maintain short-term reliability.Additionally, in a pending notice of proposed rulemaking, the
 

 

FERC is considering implementing astandard market design for wholesale markets. On October 16, 2001, we and other owners of electrictransmission lines in the southwestern U.S. filed with the FERC a request for a declaratory orderconfirming that our proposal to form WestConnect RTO, LLC would satisfy the FERC’s requirements forthe formation of an RTO. On October 10, 2002, the FERC issued an order finding that the WestConnectproposal, if modified to address specified issues, could meet the FERC’s RTO requirements andprovide the basic framework for a standard market design for the southwestern U.S. Since thattime, we have been evaluating a phased approach to RTO implementation in the desert Southwest. Weare currently participating with other entities in the southwestern U.S. in a cost/benefit analysisof implementing the WestConnect RTO, the results of which are expected to be completed in 2005.
     If we ultimately join an RTO, we could incur increased transmission-related costs and receivereduced transmission service revenues; we may be required to expand our transmission systemaccording to decisions made by the RTO rather than our internal planning process; and we mayexperience other impacts on our operations, cash flows or financial position that will not bequantifiable until the final tariffs and other material terms of the RTO are known.
     **Recent events in the energy markets that are beyond our control may have negative impacts onour business.**
     As a result of the energy crisis in California during the summer of 2001, the recentvolatility of natural gas prices in North America, the filing of bankruptcy by the EnronCorporation, and investigations by governmental authorities into energy trading activities,companies generally in the regulated and unregulated utility businesses have been under anincreased amount of public and regulatory scrutiny. The capital markets and rating agencies alsohave increased their level of scrutiny. We believe that we are in material compliance with allapplicable laws, but it is difficult or impossible to predict or control what effect these orrelated issues may have on our business or our access to the capital markets.
**Our results of operations can be adversely affected by milder weather.**
     Weather conditions directly influence the demand for electricity and affect the price ofenergy commodities. Electric power demand is generally a seasonal business. In Arizona, demand forpower peaks during the hot summer months, with market prices also peaking at that time. As aresult, our overall operating results fluctuate substantially on a seasonal basis. In addition, wehave historically sold less power, and consequently earned less income, when weather conditions aremilder. As a result, unusually mild weather could diminish our results of operations and harm ourfinancial condition.
     **If we are not able to access capital at competitive rates, our ability to implement ourfinancial strategy will be adversely affected.**
     We rely on access to short-term money markets, longer-term capital markets and the bankmarkets as a significant source of liquidity and for capital requirements not satisfied by the cashflow from our operations. We believe that we will maintain sufficient access to these financialmarkets based upon current credit ratings. However, certain market disruptions or a downgrade ofour credit ratings may increase our cost of borrowing or adversely affect our ability to access oneor more financial markets. Such disruptions could include:
 •  an economic downturn;  •  capital market conditions generally;  •  the bankruptcy of an unrelated energy company;  •  increased market prices for electricity and gas;  •  terrorist attacks or threatened attacks on our facilities or those of unrelated energy companies; or  •  the overall health of the utility industry.
     Changes in economic conditions could result in higher interest rates, which would increase ourinterest expense on our debt and reduce funds available to us for our current plans. Additionally,an increase in our leverage could adversely affect us by:
 

 

 •  increasing the cost of future debt financing;  •  increasing our vulnerability to adverse economic and industry conditions;  •  requiring us to dedicate a substantial portion of our cash flow from operations topayments on our debt, which would reduce funds available to us for operations, futurebusiness opportunities or other purposes; and  •  placing us at a competitive disadvantage compared to our competitors that have less debt.
     **A significant reduction in our credit ratings could materially and adversely affect ourbusiness, financial condition and results of operations.**
     We cannot be sure that any of our current ratings will remain in effect for any given periodof time or that a rating will not be lowered or withdrawn entirely by a rating agency if, in itsjudgment, circumstances in the future so warrant. Any downgrade could increase our borrowing costs,which would diminish our financial results. We would likely be required to pay a higher interestrate in future financings, and our potential pool of investors and funding sources could decrease.In addition, borrowing costs under certain of our existing credit facilities depend on our creditratings. A downgrade could also require us to provide additional support in the form of letters ofcredit or cash or other collateral to various counterparties. If our short-term ratings were to belowered, it could limit our access to the commercial paper market. We note that the ratings fromrating agencies are not recommendations to buy, sell or hold our securities and that each ratingshould be evaluated independently of any other rating.
     **The use of derivative contracts in the normal course of our business and changing interestrates and market conditions could result in financial losses that negatively impact our results ofoperations.**
     Our operations include managing market risks related to commodity prices and, subject tospecified risk parameters, engaging in marketing and trading activities intended to profit frommarket price movements. We are exposed to the impact of market fluctuations in the price andtransportation costs of electricity, natural gas, coal, and emissions allowances and credits. Wehave established procedures to manage risks associated with these market fluctuations by utilizingvarious commodity derivatives, including exchange-traded futures and options and over-the-counterforwards, options, and swaps. As part of our overall risk management program, we enter intoderivative transactions to hedge purchases and sales of electricity, fuels, and emissionsallowances and credits. The changes in market value of such contracts have a high correlation toprice changes in the hedged commodity.
     We are exposed to losses in the event of nonperformance or nonpayment by counterparties. Weuse a risk management process to assess and monitor the financial exposure of all counterparties.Despite the fact that the majority of trading counterparties are rated as investment grade by therating agencies, there is still a possibility that one or more of these companies could default,resulting in a material adverse impact on our earnings for a given period.
     Changing interest rates will affect interest paid on variable-rate debt and interest earned byour pension plan and nuclear decommissioning trust funds. Our policy is to manage interest ratesthrough the use of a combination of fixed-rate and floating-rate debt. The pension plan is alsoimpacted by the discount rate, which is the interest rate used to discount future pensionobligations. Continuation of recent decreases in the discount rate would result in increases inpension costs, cash contributions, and charges to other comprehensive income. The pension plan andnuclear decommissioning trust funds also have risks associated with changing market values ofequity investments. A significant portion of the pension costs and all of the nucleardecommissioning costs are recovered in regulated electricity prices.
     **Actual results could differ from estimates used to prepare our financial statements.**
     In preparing our financial statements in accordance with accounting principles generallyaccepted in the United States of America, management must often make estimates and assumptions thataffect the reported amounts of assets, liabilities, revenues, expenses and related disclosures atthe date of the financial statements and during the reporting period. Some of those judgments can be subjective and complex, and actual resultscould differ from those estimates. We consider the following accounting policies to be our mostcritical because of the uncertainties, judgments and complexities of the underlying accountingstandards and operations involved.
 •  Regulatory Accounting - Regulatory accounting allows for the actionsof regulators, such as the ACC and the FERC, to be reflected in ourfinancial statements. Their actions may cause us to capitalize coststhat would otherwise be included as an expense in the current periodby unregulated companies. If future recovery of
 

 

costs ceases to be probable, the assets would be written off as a charge in currentperiod earnings. We had $135 million of regulatory assets on ourbalance sheet at December 31, 2004. A component of the 2004Settlement Agreement, which is subject to ACC approval, would allow usto acquire the Dedicated Assets from Pinnacle West Energy, with a netcarrying value of approximately $850 million, and rate base theDedicated Assets at a rate base value of $700 million. This wouldresult in a mandatory rate base disallowance of approximately $150million. As a result, for financial reporting purposes, we wouldrecognize a one-time, after-tax net plant write-off of approximately$90 million in the period when the plant transfer to us is completedand would reduce annual depreciation expense by approximately $5million.
 •  Pensions and Other Postretirement Benefit Accounting - Changes in ouractuarial assumptions used in calculating our pension and otherpostretirement benefit liability and expense can have a significantimpact on our earnings and financial position. The most relevantactuarial assumptions are the discount rate used to measure ourliability and net periodic cost, the expected long-term rate of returnon plan assets used to estimate earnings on invested funds over thelong-term, and the assumed healthcare cost trend rates. We reviewthese assumptions on an annual basis and adjust them as necessary.  •  Derivative Accounting - Derivative accounting requires evaluation ofrules that are complex and subject to varying interpretations. Ourevaluation of these rules, as they apply to our contracts, willdetermine whether we use accrual accounting (for contracts designatedas normal) or fair value (mark-to-market) accounting. Mark-to-marketaccounting requires that changes in the fair value are recognizedperiodically in income unless certain hedge criteria are met. Forfair value hedges, the gain or loss on the derivative as well as theoffsetting loss or gain on the hedged item associated with the hedgedrisk are recognized in earnings. For cash flow hedges, changes in thefair value of the derivative are recognized in common stock equity (asa component of other comprehensive income (loss)).