AEP

Business Context and Reporting Period

This Form 10-Q covers the quarterly period ended September 30, 2000, for American Electric Power Company, Inc. (AEP) and its subsidiary registrants. The filing reflects the consolidation of AEP and Central and South West Corporation (CSW) following their merger on June 15, 2000, accounted for as a pooling of interests. AEP operates as a vertically integrated electric utility with significant wholesale marketing and trading activities across eleven states, alongside worldwide energy investments.

Key Financial Metrics (Nine Months Ended Sept 30, 2000)

Material Changes vs. Prior Period

• Revenue Growth: Total revenues increased 7.7% year-to-date, driven by a 7% increase in Domestic Electric Utilities revenues and a 9% increase in Worldwide Electric and Gas Operations. Domestic growth was fueled by higher fuel-related revenues and increased wholesale marketing sales.
• Profitability Decline: Net income decreased 37% to $489 million. Excluding extraordinary items, income before extraordinary items fell 33% to $524 million.
• Expense Increases:
  • Fuel and Purchased Power: Increased 15% due to higher natural gas prices.
  • Merger Costs: $181 million in non-recoverable merger costs were expensed in 2000 (none in 1999).
  • Cook Plant Restart: Significant costs were incurred to restart the Cook Nuclear Plant (Unit 2 returned to service in June 2000; Unit 1 expected Q1 2001).
• Extraordinary Items: AEP recorded a $35 million after-tax extraordinary loss in 2000 related to the discontinuance of regulatory accounting (SFAS 71) for generation in Ohio, Virginia, and West Virginia. This contrasts with an $8 million loss in 1999 for Texas and Arkansas.
• Cash Flow: Operating cash flow dropped significantly to $528 million from $1.193 billion, primarily due to changes in working capital (increased accounts receivable and accrued utility revenues) and the timing of fuel cost deferrals.

Guidance, Outlook, and Risks

• Industry Restructuring: AEP is transitioning from cost-based regulation to customer choice market pricing in seven states (Ohio, Texas, Virginia, West Virginia, Arkansas, Michigan, Oklahoma). This transition involves the discontinuance of SFAS 71 regulatory accounting, creating risks regarding the recovery of stranded costs and regulatory assets.
• Cook Plant Uncertainty: The restart of Cook Plant Unit 1 is scheduled for Q1 2001 but faces potential delays. Total restart costs are estimated at $719 million. Failure to restart or significant delays would materially adversely affect future results.
• Environmental Compliance: Compliance with the Federal EPA NOx rule and state regulations (e.g., Texas TNRCC) is estimated to require approximately $1.6 billion in capital expenditures. The final compliance date for the federal rule was extended to May 31, 2004.
• Legal Contingencies:
  • COLI Litigation: A potential $319 million earnings reduction (including interest) if the IRS disallows Corporate Owned Life Insurance interest deductions. AEP is litigating this matter.
  • Shareholder Litigation: Class action lawsuits allege misrepresentation regarding the Cook Plant's condition. Management intends to vigorously defend these claims.
  • EPA Clean Air Act: Ongoing litigation regarding alleged violations at coal-fired plants could result in substantial penalties and capital costs for pollution control equipment.
• Market Risk: Exposure to commodity price risk (electricity and natural gas) and foreign currency exchange rates (Brazilian Real, Chilean Peso) remains a factor, though hedging strategies are employed.

Investor Verification Checklist

• Cook Plant Restart Status: Verify the timeline and cost estimates for the restart of Cook Plant Unit 1 and the impact of any delays on future earnings.
• Regulatory Asset Recovery: Assess the probability of recovering stranded costs and regulatory assets in restructuring jurisdictions (particularly Ohio and Texas) following the discontinuance of SFAS 71.
• COLI Litigation Outcome: Monitor the progress of the COLI tax litigation, as an adverse ruling could result in a $319 million charge.
• Merger Savings Realization: Track the realization of merger savings against the rate reduction commitments made to customers in various states.
• NOx Compliance Costs: Review the final capital expenditure requirements for NOx compliance, as preliminary estimates of $1.6 billion may fluctuate.
• Working Capital Trends: Analyze the significant increase in accounts receivable and energy trading contracts on the balance sheet and its impact on liquidity.