AEP

SEC Filing Summary: American Electric Power Co. Inc. (10-Q)

Business Context and Reporting Period

This Form 10-Q covers the quarterly period ended September 30, 1998, for American Electric Power Company, Inc. (AEP) and its subsidiaries, including AEP Generating Company, Appalachian Power Company, Columbus Southern Power Company, Indiana Michigan Power Company, Kentucky Power Company, and Ohio Power Company. The filing includes consolidated financial statements and management discussion for the parent company and individual narratives for key subsidiaries.

Key Financial Metrics (Consolidated)

Amounts in thousands, except per-share data.

Material Changes vs. Prior Period

• Revenue Surge: Operating revenues increased 193% for the quarter and 114% year-to-date compared to 1997. This was driven by a significant expansion in wholesale power marketing and trading activities and warmer weather increasing retail sales.
• Net Income Volatility: Net income increased 114% for the quarter and 21% year-to-date. The year-over-year comparison is heavily influenced by a one-time extraordinary loss of $110.5 million in the third quarter of 1997 related to a U.K. windfall tax, which did not recur in 1998.
• Expense Increases: Purchased power expense rose dramatically (from $100.9M to $2.98B for the quarter) due to the growth of the trading business. Fuel expenses also increased due to higher coal-fired generation replacing unavailable nuclear capacity.
• Cook Plant Impact: The continued outage of the Cook Nuclear Plant units (since September 1997) necessitated higher-cost replacement power, impacting margins despite revenue growth.

Guidance, Outlook, and Risks

• Merger with CSW: AEP is pursuing a merger with Central and South West Corporation (CSW), targeting consummation in the second quarter of 1999. Regulatory approvals are pending from FERC, the SEC, NRC, and state commissions. The merger is conditioned on regulatory approval and accounting as a pooling of interests.
• Cook Nuclear Plant Restart: Unit 1 is expected to return to service by the end of Q1 1999; Unit 2 is anticipated 90 days later. Incremental restart costs for 1998 are estimated at $70 million. A $61 million regulatory asset has been recorded for accrued replacement energy costs, subject to regulatory recovery.
• Environmental Compliance: New EPA NOx emission rules require an estimated $1.2 billion in capital expenditures by 2003. AEP has filed a petition for review of these rules. Failure to recover these costs from customers could materially adversely affect financial condition.
• Tax Contingency (COLI): The IRS is disallowing interest deductions on Corporate Owned Life Insurance (COLI) for 1991-1996. AEP has filed suit. A disallowance could reduce earnings by approximately $310 million. AEP has made payments totaling roughly $302.7 million to avoid penalty interest, recorded as an asset pending resolution.
• Year 2000 (Y2K): AEP estimates total Y2K remediation costs between $56 million and $68 million ($15M spent to date). Mission-critical systems are targeted for completion by June 30, 1999.
• Energy Trading Risks: While trading within the traditional marketing area was profitable, non-regulated trading outside this area resulted in losses recorded in nonoperating income. Open contracts outside the traditional area have a notional value of approximately $1.34 billion ($755M sales, $585M purchases).

Investor Verification Checklist

• Cook Plant Recovery: Verify the regulatory commission's final approval of the $61 million regulatory asset for replacement energy costs.
• COLI Litigation Outcome: Monitor the status of the lawsuit against the U.S. regarding the $310 million potential earnings impact from disallowed COLI interest deductions.
• Merger Timeline: Track FERC and state regulatory approvals for the CSW merger, specifically noting any delays from the Oklahoma Corporation Commission or FERC market power studies.
• NOx Compliance Costs: Assess the finality of the EPA NOx rules and the likelihood of cost recovery through rate adjustments to mitigate the estimated $1.2 billion capital requirement.
• Trading Exposure: Review the volatility of non-regulated energy trading results, as losses in this segment offset gains from traditional marketing activities.