Why did AEP's 1995 earnings increase, and was the growth sustainable?

Earnings rose 6% mainly because unusually warm summer weather and colder fourth-quarter weather increased electricity usage, and the customer base kept growing. Those weather effects are not recurring, so part of the gain is temporary. Management also incurred a $27 million after-tax severance charge in 1995, which dampened results. Growth beyond weather depends on continued customer additions and on how retail competition and wholesale price pressure develop.

How exposed is AEP to competition and deregulation?

AEP's generation business faces growing risk. Retail customer choice is being considered in several states, including Michigan and Ohio, and wholesale price competition is intensifying. Management believes its low-cost structure gives it a favorable position, but competition would require resolving stranded-cost recovery, which could hurt earnings if regulators do not allow recovery. Transmission and distribution would likely remain regulated monopolies.

What are the main regulatory risks to AEP's cost recovery?

The company operates under PUHCA, which requires intra-system transactions to be priced at cost. Proposed repeal of PUHCA or revision of these rules could eliminate the assurance of full cost recovery for affiliated transactions, potentially with a material adverse effect on OPCo and AEP. Additional risks include the Clean Air Act compliance costs, nuclear decommissioning and spent-fuel disposal costs at the Cook Plant, and the affiliated coal mining costs at Ohio Power.

Is AEP's dividend secure, and how is the company financing growth?

The dividend has been held at $2.40 per share for several years and was covered by 1995 earnings, with a payout ratio of 84%. Construction spending is declining relative to earlier years and is expected to total about $2 billion over 1996-1998, with roughly 80% funded internally. Remaining needs are met through short-term debt, issuing common stock through the dividend reinvestment plan, and long-term debt and preferred stock issuance at the subsidiaries, which must meet earnings coverage tests to issue new securities.

AEP 10-K FY1995 Annual Report — Revenue, Net Income, EPS

01—Abstract

Summary

Summary of the 10-K filed March 28, 1996. Cited figures are marked; the original filing is the authoritative source.

American Electric Power Company, Inc. (AEP) reported 1995 net income of $530 million^a, or $2.85 per share, up 6% from $500 million ($2.71 per share) in 1994.

The increase was driven mainly by higher energy sales (120.7 billion kWh vs. 116.7 billion in 1994) from weather-related demand and customer growth, partly offset by $27 million^b after-tax severance charges tied to a functional realignment. Operating revenues rose 3% to $5.67 billion. Fuel and purchased power expense fell 6.9%, mainly from lower coal prices, but other operation expense jumped 18%, largely from Gavin Plant scrubber costs and the severance provision.

Fuel costs are generally deferred under regulatory fuel clauses, so they have limited earnings impact. The filing is a combined 10-K covering AEP and six subsidiaries. AEP is a registered holding company under PUHCA, and its earnings depend heavily on regulated utility operations, which carry a key risk: the company's cost-recovery assurances could be weakened if PUHCA is repealed or if intra-system transaction rules change.

The filing also flags competitive pressure from the move toward retail choice and wholesale open access, stranded-cost exposure on roughly $2 billion^c of regulatory assets, and the affiliated Ohio Power coal mines, whose non-Ohio shutdown costs are estimated at about $195 million after tax. Balance sheet strength improved modestly. Common equity rose to 43.1% of capitalization from 42.1%, and book value per share reached $23.25.

The dividend was held at $2.40^d per share, with the payout ratio falling to 84% from 89%. Management expects roughly $2 billion of construction spending over 1996-1998, with about 80% funded internally and no new major generating plant planned. Cook Nuclear Plant decommissioning and spent-fuel disposal costs remain uncertain, and the company has $372 million of unused short-term credit lines.

02—Key points

Key Highlights

Net income rose 6% to $530 million ($2.85/share) from $500 million ($2.71/share) in 1994, driven by a 3.5% increase in kWh sales to 120.7 billion kWh.
Operating revenues grew 3% to $5.67 billion; fuel and purchased power expense fell 6.9% on lower coal contract prices, while other operation expense rose 18.1%.
Common equity ratio improved to 43.1% (from 42.1%), with total common shareholders' equity of $4.34 billion and book value of $23.25 per share.
The $2.40 annual dividend was maintained, and the payout ratio improved to 84% from 89%.
Roughly $2 billion in construction spending is planned for 1996-1998, about 80% funded internally, with no major new generating plant committed.
Approximately $2 billion of regulatory assets and a possible PUHCA repeal create exposure to stranded costs and changes in intra-system cost recovery.
The affiliated Ohio Power coal mines carry about $195 million (after tax) of potential non-Ohio shutdown costs, and Phase II Clean Air Act compliance may force closures by January 2000.

03—Questions

Frequently Asked Questions

Why did AEP's 1995 earnings increase, and was the growth sustainable?
Earnings rose 6% mainly because unusually warm summer weather and colder fourth-quarter weather increased electricity usage, and the customer base kept growing. Those weather effects are not recurring, so part of the gain is temporary. Management also incurred a $27 million after-tax severance charge in 1995, which dampened results. Growth beyond weather depends on continued customer additions and on how retail competition and wholesale price pressure develop.
How exposed is AEP to competition and deregulation?
AEP's generation business faces growing risk. Retail customer choice is being considered in several states, including Michigan and Ohio, and wholesale price competition is intensifying. Management believes its low-cost structure gives it a favorable position, but competition would require resolving stranded-cost recovery, which could hurt earnings if regulators do not allow recovery. Transmission and distribution would likely remain regulated monopolies.
What are the main regulatory risks to AEP's cost recovery?
The company operates under PUHCA, which requires intra-system transactions to be priced at cost. Proposed repeal of PUHCA or revision of these rules could eliminate the assurance of full cost recovery for affiliated transactions, potentially with a material adverse effect on OPCo and AEP. Additional risks include the Clean Air Act compliance costs, nuclear decommissioning and spent-fuel disposal costs at the Cook Plant, and the affiliated coal mining costs at Ohio Power.
Is AEP's dividend secure, and how is the company financing growth?
The dividend has been held at $2.40 per share for several years and was covered by 1995 earnings, with a payout ratio of 84%. Construction spending is declining relative to earlier years and is expected to total about $2 billion over 1996-1998, with roughly 80% funded internally. Remaining needs are met through short-term debt, issuing common stock through the dividend reinvestment plan, and long-term debt and preferred stock issuance at the subsidiaries, which must meet earnings coverage tests to issue new securities.

04—Continue

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