AEP

Business Context and Reporting Period

This Form 10-Q covers the quarterly period ended September 30, 2003, for American Electric Power Company, Inc. (AEP) and its subsidiary registrants. AEP is a major electric utility holding company operating in multiple states, including Ohio, Texas, Kentucky, Indiana, Michigan, Virginia, West Virginia, Oklahoma, Arkansas, and Louisiana. The filing includes consolidated financial statements and separate reports for ten subsidiary registrants, such as AEP Generating Company, Appalachian Power Company, and Southwestern Electric Power Company.

Key Financial Metrics

Note: Total Debt calculated as Short-term Debt ($443M) + Long-term Debt Due Within One Year ($1,234M) + Long-term Debt ($12,323M). 2002 debt figures derived from balance sheet data.

Material Changes vs. Prior Period

• Net Income Decline (Q3): Net income decreased 40% to $257 million from $425 million in Q3 2002. This was primarily driven by unfavorable weather (mild cooling season), a weak economy reducing industrial demand, and the loss of contributions from Texas retail electricity providers sold in late 2002.
• Net Income Increase (9 Months): Despite the Q3 decline, nine-month net income rose 174% to $872 million from $318 million. This increase was significantly aided by a $242 million net-of-tax gain from the cumulative effect of adopting SFAS 143 (Asset Retirement Obligations) and a $193 million net-of-tax gain from the cumulative effect of accounting changes in 2003, compared to a $350 million charge in 2002 for SFAS 142 (Goodwill).
• Utility Operations: Utility operating income decreased $33 million in Q3 due to lower retail margins and reduced demand. However, for the nine months, utility operating income increased $40 million, driven by higher system sales revenues and non-cash earnings from Texas capacity auction true-ups ($169 million).
• Investments: UK Operations reported a net loss of $51 million in Q3 (vs. $5 million loss in 2002) due to timing differences in coal and freight contracts. Gas Operations reported a net loss of $20 million in Q3 (vs. $5 million gain in 2002) due to reduced margins and the absence of mark-to-market gains recorded in the prior year.
• Dividend Reduction: In April 2003, the Board reduced the quarterly common stock dividend to $0.35 per share (from $0.60), resulting in annual cash savings of approximately $395 million.

Guidance, Outlook, and Risks

• Divestitures: AEP is actively seeking to divest non-regulated assets, including 4,497 MW of unregulated generation capacity in Texas, its coal business, and independent power producers (IPPs). Two IPP investments were impaired by $70 million in Q3 2003.
• Texas Restructuring (2004 True-Up): A significant regulatory risk exists regarding the 2004 true-up proceeding in Texas. AEP has recorded $431 million in regulatory assets related to the wholesale capacity auction true-up. However, the Public Utility Commission of Texas (PUCT) Staff has proposed a calculation methodology that differs from AEP's, which could require an adjustment to these assets. A coalition of consumer groups petitioned to amend the rule, which the PUCT denied in November 2003, but the risk of reduced recovery remains.
• Environmental Compliance: Compliance with the Federal EPA NOx Rule and Section 126 Rule is required by May 31, 2004. Estimated capital expenditures range from $1.3 billion to $1.7 billion, with approximately $1 billion spent through September 30, 2003. Failure to recover these costs through rates could materially impact results.
• Legal Proceedings:
  • Enron Bankruptcy: Enron filed a complaint in September 2003 seeking approximately $125 million plus interest, challenging AEP's offsetting of receivables and payables. AEP intends to assert its right to offset.
  • CFTC Complaint: The CFTC filed a complaint in September 2003 alleging AEP provided false information to manipulate natural gas prices. Management does not expect a material effect but cannot predict the outcome.
  • Clean Air Act Litigation: Ongoing litigation regarding generating plant emissions modifications. Management cannot estimate the loss or range of loss.
• RTO Formation: Delays in joining the PJM Regional Transmission Organization (RTO) for AEP East companies persist due to state regulatory hurdles (e.g., Kentucky, Virginia). If approval is not obtained, AEP may be required to reimburse PJM for implementation costs estimated at $23 million.

Investor Verification Checklist

• Texas Regulatory Asset Recovery: Verify the final methodology approved by the PUCT for the 2004 true-up proceeding and its impact on the $431 million regulatory asset recorded for the wholesale capacity auction true-up.
• Divestiture Progress: Monitor the status of the sale of Texas unregulated generation assets and the coal business, as well as the valuation of remaining non-core investments.
• Environmental Capital Expenditures: Track actual spending against the $1.3 billion to $1.7 billion estimate for NOx compliance and confirm rate recovery mechanisms for these costs.
• Legal Exposure: Review developments in the CFTC complaint, Enron bankruptcy proceedings, and Clean Air Act litigation for potential penalties or remediation costs.
• Weather Sensitivity: Assess the impact of weather normalization on retail sales volumes and margins in the upcoming quarters, given the significant variance in cooling degree days in Q3 2003.