ALABAMA POWER CO - Annual Report: 2004 (Form 10-K)

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION

FORM 10-K

þ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year Ended December 31, 2004
OR
o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934
For the Transition Period from       to      

Securities registered pursuant to Section 12(b) of the Act:¹

Each of the following classes or series of securities registered pursuant to Section 12(b) of the Act is listed on the New York Stock Exchange.

Securities registered pursuant to Section 12(g) of the Act: ⁷

      Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes þ No o

      Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrants’ knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. o

      Indicate by check mark whether the registrant is an accelerated filer (as defined by Rule 12b-2 of the Securities Exchange Act of 1934).

      Aggregate market value of voting and non-voting stock held by non-affiliates of The Southern Company at June 30, 2004: $21.5 billion. All of the common stock of the other registrants is held by The Southern Company. A description of each registrant’s common stock follows:

      Documents incorporated by reference: specified portions of The Southern Company’s Proxy Statement relating to the 2005 Annual Meeting of Stockholders are incorporated by reference into PART III. In addition, specified portions of the Information Statements of Alabama Power Company, Georgia Power Company, Gulf Power Company and Mississippi Power Company relating to each of their respective 2005 Annual Meetings of Shareholders are incorporated by reference into PART III.

      Southern Power meets the conditions set forth in General Instructions I(1)(a) and (b) of Form 10-K and is therefore filing this Form 10-K with the reduced disclosure format specified in General Instructions I(2)(b) and (c) of Form 10-K.

      This combined Form 10-K is separately filed by The Southern Company, Alabama Power Company, Georgia Power Company, Gulf Power Company, Mississippi Power Company, Savannah Electric and Power Company and Southern Power Company. Information contained herein relating to any individual company is filed by such company on its own behalf. Each company makes no representation as to information relating to the other companies.

Table of Contents

DEFINITIONS

When used in Items 1 through 5 and Items 9A through 15, the following terms will have the meanings indicated.

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DEFINITIONS
(continued)

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CAUTIONARY STATEMENT REGARDING
FORWARD-LOOKING INFORMATION

      This Annual Report on Form 10-K contains forward-looking statements. Forward-looking statements include, among other things, statements concerning the strategic goals for Southern Company’s wholesale business, retail sales growth, storm damage cost recovery, environmental regulations and expenditures, projections for postretirement benefit trust contributions, completion of construction projects and estimated construction and other expenditures. In some cases, forward-looking statements can be identified by terminology such as “may,” “will,” “could,” “should,” “expects,” “plans,” “anticipates,” “believes,” “estimates,” “projects,” “predicts,” “potential” or “continue” or the negative of these terms or other similar terminology. There are various factors that could cause actual results to differ materially from those suggested by the forward-looking statements; accordingly, there can be no assurance that such indicated results will be realized. These factors include:

Southern Company and its subsidiaries expressly disclaim any obligation to update any forward-looking statements.

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PART I

Item 1. BUSINESS

      Southern Company was incorporated under the laws of Delaware on November 9, 1945. Southern Company is domesticated under the laws of Georgia and is qualified to do business as a foreign corporation under the laws of Alabama. Southern Company owns all the outstanding common stock of Alabama Power, Georgia Power, Gulf Power, Mississippi Power and Savannah Electric, each of which is an operating public utility company. The retail operating companies supply electric service in the states of Alabama, Georgia, Florida, Mississippi and Georgia, respectively. More particular information relating to each of the retail operating companies is as follows:

Alabama Power is a corporation organized under the laws of the State of Alabama on November 10, 1927, by the consolidation of a predecessor Alabama Power Company, Gulf Electric Company and Houston Power Company. The predecessor Alabama Power Company had had a continuous existence since its incorporation in 1906.

Georgia Power was incorporated under the laws of the State of Georgia on June 26, 1930, and admitted to do business in Alabama on September 15, 1948.

Gulf Power is a corporation which was organized under the laws of the State of Maine on November 2, 1925, and admitted to do business in Florida on January 15, 1926, in Mississippi on October 25, 1976, and in Georgia on November 20, 1984.

Mississippi Power was incorporated under the laws of the State of Mississippi on July 12, 1972, was admitted to do business in Alabama on November 28, 1972, and effective December 21, 1972, by the merger into it of the predecessor Mississippi Power Company, succeeded to the business and properties of the latter company. The predecessor Mississippi Power Company was incorporated under the laws of the State of Maine on November 24, 1924, and was admitted to do business in Mississippi on December 23, 1924, and in Alabama on December 7, 1962.

Savannah Electric is a corporation existing under the laws of the State of Georgia; its charter was granted by the Secretary of State on August 5, 1921.

      In addition, Southern Company owns all of the common stock of Southern Power, which is also an operating public utility company. Southern Power constructs, owns and manages Southern Company’s competitive generation assets and sells electricity at market-based rates in the wholesale market. Southern Power is a corporation organized under the laws of Delaware on January 8, 2001, and admitted to do business in Alabama, Florida and Georgia on January 10, 2001 and in Mississippi on January 30, 2001.

      Southern Company also owns all the outstanding common stock of SouthernLINC Wireless, Southern Company GAS, Southern Nuclear, SCS, Southern Telecom, Southern Holdings and other direct and indirect subsidiaries. SouthernLINC Wireless provides digital wireless communications services to the retail operating companies and also markets these services to the public within the Southeast. Southern Company GAS, which began operation in August 2002, is a competitive retail natural gas marketer serving communities in Georgia. Southern Nuclear provides services to Alabama Power’s and Georgia Power’s nuclear plants. SCS is the system service company providing, at cost, specialized services to Southern Company and its subsidiary companies. Southern Telecom provides wholesale fiber optic solutions to telecommunication providers in the Southeastern United States. Southern Holdings is an intermediate holding subsidiary for Southern Company’s investments in synthetic fuels and leveraged leases and various other energy-related businesses.

      Alabama Power and Georgia Power each own 50% of the outstanding common stock of SEGCO. SEGCO is an operating public utility company that owns electric generating units with an aggregate capacity of 1,019,680 kilowatts at Plant Gaston on the Coosa River near Wilsonville, Alabama. Alabama Power and Georgia Power are each entitled to one-half of SEGCO’s capacity and energy. Alabama Power acts as SEGCO’s agent in the operation of SEGCO’s units and furnishes coal to SEGCO as fuel for its units. SEGCO also owns three 230,000 volt transmission lines extending from Plant Gaston to the Georgia state line at which point connection is made with the Georgia Power transmission line system.

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      See Note 10 to the financial statements of Southern Company in Item 8 herein for additional information regarding Southern Company’s segment and related information.

      The registrants’ Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and all amendments to those reports are made available on Southern Company’s website, free of charge, as soon as reasonably practicable after such material is electronically filed with or furnished to the SEC. Southern Company’s internet address is http://www.southerncompany.com.

The SOUTHERN System

Retail Operating Companies

The transmission facilities of each of the retail operating companies are connected to the respective company’s own generating plants and other sources of power and are interconnected with the transmission facilities of the other retail operating companies and SEGCO by means of heavy-duty high voltage lines. For information on Georgia Power’s integrated transmission system, see BUSINESS — “Territory Served by the Utilities” in Item 1 herein for additional information.

      Operating contracts covering arrangements in effect with principal neighboring utility systems provide for capacity exchanges, capacity purchases and sales, transfers of economy energy and other similar transactions. Additionally, the retail operating companies have entered into voluntary reliability agreements with the subsidiaries of Entergy Corporation, Florida Electric Power Coordinating Group and TVA and with Carolina Power & Light Company, Duke Energy Corporation, South Carolina Electric & Gas Company and Virginia Electric and Power Company, each of which provides for the establishment and periodic review of principles and procedures for planning and operation of generation and transmission facilities, maintenance schedules, load retention programs, emergency operations and other matters affecting the reliability of bulk power supply. The retail operating companies have joined with other utilities in the Southeast (including those referred to above) to form the SERC to augment further the reliability and adequacy of bulk power supply. Through the SERC, the retail operating companies are represented on the National Electric Reliability Council.

      An intra-system interchange agreement provides for coordinating operations of the power producing facilities of the retail operating companies and Southern Power and the capacities available to such companies from non-affiliated sources and for the pooling of surplus energy available for interchange. Coordinated operation of the entire interconnected system is conducted through a central power supply coordination office maintained by SCS. The available sources of energy are allocated to the retail operating companies and Southern Power to provide the most economical sources of power consistent with reliable operation. The resulting benefits and savings are apportioned among each of the companies.

      SCS has contracted with Southern Company, each retail operating company, Southern Power, Southern Nuclear, SEGCO and other subsidiaries to furnish, at direct or allocated cost and upon request, the following services: general and design engineering, purchasing, accounting and statistical analysis, finance and treasury, tax, information resources, marketing, auditing, insurance and pension administration, human resources, systems and procedures and other services with respect to business and operations and power pool transactions. Southern Power, Southern Company GAS, SouthernLINC Wireless and Southern Telecom have also secured from the retail operating companies certain services which are furnished at cost.

      Southern Nuclear has contracts with Alabama Power to operate Plant Farley and with Georgia Power to operate Plants Hatch and Vogtle. See BUSINESS — “Regulation — Atomic Energy Act of 1954” in Item 1 herein for additional information.

Southern Power

Southern Power is an electric wholesale generation subsidiary with market-based rates. Southern Power constructs, owns and manages generating facilities and sells the output under long-term, fixed-price capacity contracts both to unaffiliated wholesale purchasers as well as to the retail operating companies (under PPAs approved by the respective PSCs). Southern Power’s business activities are not subject to traditional state regulation of utilities but are subject to regulation by the

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FERC. Southern Power has attempted to insulate itself from significant fuel supply, fuel transportation and electric transmission risks by making such risks the responsibility of the counterparties to the PPAs. However, Southern Power’s overall profit will depend on the parameters of the wholesale market and its efficient operation of its wholesale generating assets. At December 31, 2004, Southern Power had approximately 4,775 megawatts of generating capacity in commercial operation.

Other Business

In June 2002, Southern Company formed a wholly-owned subsidiary, Southern Company GAS. Southern Company GAS operates as a retail gas marketer in the State of Georgia. Southern Company GAS completed its acquisition out of bankruptcy from The New Power Company (New Power) and began operations in July 2002. Southern Company GAS also purchased proprietary risk management software and hardware systems, natural gas inventory and accounts receivable from New Power. The total purchase price was approximately $60 million. Southern Company GAS has a 12.2% market share as of December 31, 2004.

      Southern Holdings is an intermediate holding subsidiary for Southern Company’s investments in leveraged leases and synthetic fuel products, in addition to Southern Company Energy Solutions LLC, which provides energy services.

      In 1996, SouthernLINC Wireless began serving Southern Company’s retail operating companies and marketing its services to non-affiliates within the Southeast. Its system covers approximately 127,000 square miles and combines the functions of two-way radio dispatch, cellular phone, short text and numeric messaging and wireless internet access and data transfer.

      These continuing efforts to invest in and develop new business opportunities offer potential returns exceeding those of rate-regulated operations. However, these activities also involve a higher degree of risk.

Risk Factors

In addition to the other information in this Form 10-K and other documents filed by Southern Company and/or its subsidiaries with the SEC from time to time, the following factors should be carefully considered in evaluating Southern Company and its subsidiaries. Such factors could affect actual results and cause results to differ materially from those expressed in any forward-looking statements made by, or on behalf of, Southern Company and/or its subsidiaries. Some or all of these factors may apply to Southern Company and/or its subsidiaries.

Risks Related to the Energy Industry

Southern Company is subject to substantial governmental regulation. Compliance with current and future regulatory requirements and procurement of necessary approvals, permits and certificates may result in substantial costs to Southern Company.

      Southern Company is subject to substantial regulation from federal, state and local regulatory agencies. Southern Company and its subsidiaries are required to comply with numerous laws and regulations and to obtain numerous permits, approvals and certificates from the governmental agencies that regulate various aspects of their businesses, including customer rates, service regulations, retail service territories, sales of securities, asset acquisitions and sales, accounting policies and practices and the operation of fossil-fuel, hydroelectric and nuclear generating facilities. For example, the rates charged to wholesale customers by the retail operating companies and by Southern Power must be approved by the FERC. In addition, the respective state PSCs must approve the retail operating companies’ rates for retail customers. Southern Company believes the necessary permits, approvals and certificates have been obtained for its existing operations and that its business is conducted in accordance with applicable laws; however, Southern Company is unable to predict the impact on its operating results from future regulatory activities of these agencies.

      Southern Company is also subject to regulation by the SEC under the Holding Company Act. The rules and regulations promulgated under the Holding Company Act impose a number of restrictions on the

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operations of registered utility holding companies and their subsidiaries. These restrictions include a requirement that, subject to a number of exceptions, the SEC approve in advance securities issuances, acquisitions and dispositions of utility assets or of securities of utility companies and acquisitions of other businesses. The Holding Company Act also generally limits the operations of a registered holding company to a single integrated public utility system, plus additional energy-related businesses. The Holding Company Act requires that transactions between affiliated companies in a registered holding company system be performed at cost, with limited exceptions.

      The impact of any future revision or changes in interpretations of existing regulations or the adoption of new laws and regulations applicable to Southern Company or any of its subsidiaries cannot now be predicted. Changes in regulation or the imposition of additional regulations could influence Southern Company’s operating environment and may result in substantial costs to Southern Company.

General Risks Related to Operation of Southern Company’s Utility Subsidiaries

The regional power market in which Southern Company and its subsidiaries compete has changing transmission regulatory structures, which could affect the ownership of these assets and related revenues and expenses.

      The retail operating companies currently own and operate transmission facilities as part of a vertically integrated utility. Transmission revenues are not separated from generation and distribution revenues in their approved retail rates. Federal governmental authorities are advocating the formation of RTOs and are proposing the adoption of new regulations that would impact electric markets, including the transmission regulatory structure. Under this new transmission regulatory structure, the retail operating companies would transfer functional control (but not ownership) of their transmission facilities to an independent third party. Because it remains unclear how RTOs will develop or what new market rules will be established, Southern Company is unable to assess fully the impact that these developments may have on its business. Southern Company’s revenues, expenses, assets and liabilities could be adversely affected by changes in the transmission regulatory structure in its regional power market.

Certain events in the energy markets that are beyond Southern Company’s control have increased the level of public and regulatory scrutiny in the energy industry and in the capital markets. The reaction to these events may result in new laws or regulations related to Southern Company’s business operations or the accounting treatment of its existing operations which could have a negative impact on Southern Company’s net income or access to capital.

      As a result of the energy crisis in California during the summer of 2001, the filing of bankruptcy by Enron Corporation, investigations by governmental authorities into energy trading activities and the August 2003 power outage in the Northeast, companies in regulated and unregulated electric utility businesses have been under an increased amount of public and regulatory scrutiny with respect to, among other things, accounting practices, financial disclosures and relationships with independent auditors. The capital markets and ratings agencies also have increased their level of scrutiny. This increased scrutiny could lead to substantial changes in laws and regulations affecting Southern Company, including new accounting standards that could change the way Southern Company is required to record revenues, expenses, assets and liabilities. These types of disruptions in the industry and any resulting regulations may have a negative impact on Southern Company’s net income or access to capital.

Deregulation or restructuring in the electric industry may result in increased competition and unrecovered costs which could negatively impact Southern Company’s earnings and the value of its assets.

      Increased competition, which may result from restructuring efforts, could have a significant adverse financial impact on Southern Company and its retail operating companies. Increased competition could result in increased pressure to lower the cost of electricity. Any adoption in the territories served by the retail operating companies of retail competition and the unbundling of regulated energy service could have a significant adverse financial impact on Southern Company and the retail operating companies due to an impairment of assets, a loss of retail customers, lower profit margins, an inability to recover reasonable costs or increased costs of capital. Southern Company cannot

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predict if or when it will be subject to changes in legislation or regulation, nor can Southern Company predict the impact of these changes.

      Additionally, the electric utility industry has experienced a substantial increase in competition at the wholesale level, caused by changes in federal law and regulatory policy. As a result of the Public Utility Regulatory Policies Act of 1978 and the Energy Act, competition in the wholesale electricity market has greatly increased due to a greater participation by traditional electricity suppliers, non-utility generators, independent power producers, wholesale power marketers and brokers, and due to the trading of energy futures contracts on various commodities exchanges. In 1996, the FERC issued new rules on transmission service to facilitate competition in the wholesale market on a nationwide basis. The rules give greater flexibility and more choices to wholesale power customers.

Potential changes to the criteria used by the FERC for approval of market-based contracts may negatively impact the retail operating companies’ and Southern Power’s ability to charge market-based rates.

Each of the retail operating companies and Southern Power have authorization from the FERC to sell power to nonaffiliates at market-based prices. The retail operating companies and Southern Power also have FERC authority to make short-term opportunity sales at market rates. Specific FERC approval must be obtained with respect to a market-based contract with an affiliate. In November 2001, the FERC modified the test it uses to consider utilities’ applications to charge market-based rates and adopted a new test called the Supply Margin Assessment (SMA). The FERC applied the SMA to several utilities, including Southern Company, the retail operating companies and Southern Power, and found Southern Company and others to be “pivotal suppliers” in their retail service territories and ordered the implementation of several mitigation measures. Southern Company and others sought rehearing of the FERC order, and the FERC delayed the implementation of certain mitigation measures. In April 2004, the FERC issued an order that abandoned the SMA test and adopted a new interim analysis for measuring generation market power. This new interim approach requires utilities to submit a pivotal supplier screen and a wholesale market share screen. If the applicant does not pass both screens, there will be a rebuttable presumption regarding generation market power. The FERC’s order also sets forth procedures for rebutting these presumptions and addresses mitigation measures for those entities that are found to have market power. In the absence of specific mitigation measures, the order includes several cost-based mitigation measures that would apply by default. The FERC also initiated a new rulemaking proceeding that, among other things, will adopt a final methodology for assessing generation market power.

      In July 2004, the FERC denied Southern Company’s request for rehearing, along with a number of others, and reaffirmed the interim tests that it adopted in April 2004. In August 2004, Southern Company submitted a filing to the FERC that included results showing that Southern Company passed the pivotal supplier screen for all markets and the wholesale market share screen for all markets except the Southern Company retail service territory. Southern Company also submitted other analyses to demonstrate that it lacks generation market power. On December 17, 2004, the FERC initiated a proceeding to assess Southern Company’s generation dominance within its retail service territory. The ability to charge market-based rates in other markets is not at issue. As directed by this order, on February 15, 2005, Southern Company submitted additional information related to generation dominance in its retail service territory. Any new market-based rate transactions in the Southern Company retail service territory entered into after February 27, 2005 will be subject to refund to the level of the default cost-based rates, pending the outcome of the proceeding. Southern Company, along with other utilities, has also filed an appeal of the FERC’s April and July 2004 orders with the U.S. Court of Appeals for the District of Columbia Circuit. The FERC has asked the court to dismiss the appeal on the grounds that it is premature.

      In the event that the FERC’s default mitigation measures are ultimately applied, Southern Power and the retail operating companies may be required to charge cost-based rates for certain wholesale sales in the Southern Company retail service territory, which may be lower than negotiated market-based rates. The final outcome of this matter will depend on

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the form in which the final methodology for assessing generation market power and mitigation rules may be ultimately adopted and cannot be determined at this time.

Risks Related to Environmental Regulation

Southern Company’s costs of compliance with environmental laws are significant. The costs of compliance with future environmental laws and the incurrence of environmental liabilities could harm Southern Company’s cash flow and profitability.

      Southern Company and its subsidiaries are subject to extensive federal, state and local environmental requirements which, among other things, regulate air emissions, water discharges and the management of hazardous and solid waste in order to adequately protect the environment. Compliance with these legal requirements requires Southern Company to commit significant expenditures for installation of pollution control equipment, environmental monitoring, emissions fees and permits at all of its facilities. These expenditures are significant and Southern Company expects that they will increase in the future. For example, construction expenditures for achieving compliance with Title IV of the Clean Air Act totaled approximately $400 million. Construction expenditures for compliance with the nitrogen oxide emission reduction requirements totaled approximately $1.1 billion through 2004 with an additional $500 million committed through 2007 for the states of Alabama and Georgia.

      Litigation over environmental issues and claims of various types, including property damage, personal injury, and citizen enforcement of environmental requirements, has increased generally throughout the United States. In particular, personal injury claims for damages caused by alleged exposure to hazardous materials have become more frequent. Although the ultimate outcome of such litigation cannot be predicted, management does not anticipate that the liabilities, if any, arising from such current proceedings would have a material adverse effect on the financial condition of Southern Company and its subsidiaries.

      If Southern Company fails to comply with environmental laws and regulations, even if caused by factors beyond its control, that failure may result in the assessment of civil or criminal penalties and fines against Southern Company. The EPA has filed civil actions against Alabama Power, Georgia Power and Savannah Electric alleging violations of the new source review provisions of the Clean Air Act. The EPA has also issued notices of violation to Gulf Power and Mississippi Power. In addition, Georgia Power is a party to a civil suit regarding alleged violations of the Clean Air Act at four units of Plant Wansley. Attorneys general from eight states, each outside of Southern Company’s service territory, and the corporation counsel for New York City filed a complaint in the U.S. District Court for the Southern District of New York against Southern Company and four other electric power companies. A nearly identical complaint was filed by three environmental groups in the same court. The complaints allege that the companies’ emissions of carbon dioxide, a greenhouse gas, contribute to global warming, which the plaintiffs assert is a public nuisance. An adverse outcome in any one of these cases could require substantial capital expenditures that cannot be determined at this time and/or could require payment of substantial penalties.

      Existing environmental laws and regulations may be revised or new laws and regulations seeking to protect the environment may be adopted or become applicable to Southern Company. Revised or additional laws and regulations could result in significant additional expense and operating restrictions on Southern Company’s facilities or increased compliance costs which may not be fully recoverable from Southern Company’s customers and would therefore reduce Southern Company’s net income. The cost impact of such legislation would depend upon the specific requirements enacted and cannot be determined at this time.

Risks Related to Southern Company and its Business

Southern Company may be unable to meet its ongoing and future financial obligations and to pay dividends on its common stock if its subsidiaries are unable to pay upstream dividends or repay funds to Southern Company.

      Southern Company is a holding company and, as such, Southern Company has no operations of its own. Southern Company’s ability to meet its financial obligations and to pay dividends on its common stock at the current rate is primarily dependent on the earnings and cash flows of its subsidiaries and their ability to pay upstream dividends or to repay funds to Southern

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Company. Prior to funding Southern Company, Southern Company’s subsidiaries have financial obligations that must be satisfied, including among others, debt service and preferred stock dividends. In addition, the Holding Company Act rules limit the dividends that Southern Company’s subsidiaries may pay from unearned surplus.

Southern Company’s financial performance may be adversely affected if its subsidiaries are unable to successfully operate their facilities.

      Southern Company’s financial performance depends on the successful operation of its subsidiaries’ electric generating, transmission and distribution facilities. Operating these facilities involves many risks, including:

      A decrease or elimination of revenues from power produced by the electric generating facilities or an increase in the cost of operating the facilities would reduce Southern Company’s net income and could decrease or eliminate funds available to Southern Company.

      In addition, Southern Company’s non-utility businesses depend on the successful operation of their respective facilities. For example, SouthernLINC Wireless’ business could be adversely impacted in the event of a break-down of its telecommunications facilities.

Through its subsidiaries, Southern Company’s revenues depend in part on sales under PPAs. The failure of a counterparty to one of these PPAs to perform its obligations, or the failure to renew the PPAs, could have a negative impact on Southern Company’s earnings.

      Most of Southern Power’s generating capacity has been sold to purchasers under PPAs having initial terms of five to 15 years. In addition, the retail operating companies also enter into PPAs with non-affiliated parties. Southern Company’s revenues are dependent on the continued performance by the purchasers of their obligations under the PPAs. Even though Southern Power and the retail operating companies have a rigorous credit evaluation, the failure of one of the purchasers to perform its obligations could have a negative impact on Southern Company’s earnings. Although these credit evaluations take into account the possibility of default by a purchaser, Southern Company’s actual exposure to a default by a purchaser may be greater than the credit evaluation predicts. Neither Southern Power nor the retail operating companies can predict whether the PPAs will be renewed at the end of their respective terms or on what terms any renewals may be made. If a PPA is not renewed, a replacement PPA cannot be assured.

Southern Company and its subsidiaries may incur additional costs or delays in power plant construction and may not be able to recover their investment. Southern Company’s facilities require ongoing capital expenditures.

      Certain of the retail operating companies and Southern Power are in the process of constructing new generating facilities. Southern Company intends to continue its strategy of developing and constructing other new facilities and expanding existing facilities. The completion of these facilities without delays or cost overruns is subject to substantial risks, including:

      If a retail operating company or Southern Power is unable to complete the development or construction of a

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facility, or if a retail operating company or Southern Power decides to delay or cancel construction of a facility, it may not be able to recover its investment in that facility. In addition, construction delays and contractor performance shortfalls can result in the loss of revenues and may, in turn, adversely affect the results of operations and financial position of a retail operating company or Southern Power. Furthermore, if construction projects are not completed according to specification, a retail operating company or Southern Power may incur liabilities and suffer reduced plant efficiency, higher operating costs and reduced earnings.

      Once facilities come into commercial operation, ongoing capital expenditures are required to maintain reliable levels of operation. Significant portions of the retail operating companies’ existing facilities were constructed many years ago. Older generation equipment, even if maintained in accordance with good engineering practices, may require significant capital expenditures to maintain efficiency, to comply with changing environmental requirements or to provide reliable operations.

Changes in technology may make Southern Company’s electric generating facilities less competitive.

      A key element of Southern Company’s business model is that generating power at central power plants achieves economies of scale and produces power at relatively low cost. There are other technologies that produce power, most notably fuel cells, microturbines, windmills and solar cells. It is possible that advances in technology will reduce the cost of alternative methods of producing power to a level that is competitive with that of most central power station electric production. If this were to happen and if these technologies achieved economies of scale, Southern Company’s market share could be eroded, and the value of its electric generating facilities could be reduced. Changes in technology could also alter the channels through which retail electric customers buy power, which could reduce Southern Company’s revenues or increase expenses.

Operation of nuclear facilities involves inherent risks, including environmental, health, regulatory, terrorism and financial risks that could result in fines or the closure of Southern Company’s nuclear units, and which may present potential exposures in excess of Southern Company’s insurance coverage.

      Southern Company owns six nuclear units through Alabama Power (two units) and through Georgia Power, which holds undivided interests in, and contracts for operation of, four units. These six nuclear units are operated by Southern Nuclear and represent approximately 3,680 megawatts, or 9.5% of Southern Company’s generation capacity as of December 31, 2004. Southern Company’s nuclear facilities are subject to environmental, health and financial risks such as on-site storage of spent nuclear fuel, the ability to dispose of such spent nuclear fuel, the ability to maintain adequate reserves for decommissioning, potential liabilities arising out of the operation of these facilities and the threat of a possible terrorist attack. Southern Company maintains decommissioning trusts and external insurance coverage to minimize the financial exposure to these risks; however, it is possible that damages could exceed the amount of Southern Company’s insurance coverage.

      The NRC has broad authority under federal law to impose licensing and safety-related requirements for the operation of nuclear generation facilities. In the event of non-compliance, the NRC has the authority to impose fines or shut down a unit, or both, depending upon its assessment of the severity of the situation, until compliance is achieved. Recent NRC orders related to increased security measures and any future safety requirements promulgated by the NRC could require Southern Company to make substantial operating and capital expenditures at its nuclear plants. In addition, although Southern Company has no reason to anticipate a serious nuclear incident at its plants, if an incident did occur, it could result in substantial costs to Southern Company. A major incident at a nuclear facility anywhere in the world could cause the NRC to limit or prohibit the operation or licensing of any domestic nuclear unit.

      Southern Company’s nuclear units require licenses that, in some cases, need to be renewed or extended in order to continue operating beyond their initial forty-year terms. As a result of potential terrorist threats and increased public scrutiny of utilities, the licensing process could result in increased licensing or compliance costs that are difficult or impossible to predict.

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Southern Company’s generation and energy marketing operations are subject to risks, many of which are beyond its control, that may reduce Southern Company’s revenues and increase its costs.

      Southern Company’s generation and energy marketing operations are subject to changes in power prices or fuel costs, which could increase the cost of producing power or decrease the amount Southern Company receives from the sale of power. The market prices for these commodities may fluctuate over relatively short periods of time. Southern Company attempts to mitigate risks associated with fluctuating fuel costs by passing these costs on to customers through retail fuel cost recovery or in its PPAs. Among the factors that could influence power prices and fuel costs are:

      Certain of these factors could increase Southern Company’s expenses. For the retail operating companies, such increases may not be fully recoverable through rates. Other of these factors could reduce Southern Company’s revenues.

The use of derivative contracts by Southern Company and its subsidiaries in the normal course of business could result in financial losses that negatively impact the results of operations of Southern Company and its subsidiaries.

      Southern Company and its subsidiaries use derivative instruments, such as swaps, options, futures and forwards, to manage their commodity and financial market risks and, to a lesser extent, engage in limited trading activities. Southern Company and its subsidiaries could recognize financial losses as a result of volatility in the market values of these contracts, or if a counterparty fails to perform. In the absence of actively quoted market prices and pricing information from external sources, the valuation of these financial instruments can involve management’s judgment or use of estimates. As a result, changes in the underlying assumptions or use of alternative valuation methods could affect the value of the reported fair value of these contracts.

Southern Company may not be able to obtain adequate fuel supplies, which could limit its ability to operate its facilities.

      Southern Company purchases fuel from a number of suppliers. Disruption in the delivery of fuel, including disruptions as a result of, among other things, weather, labor relations or environmental regulations affecting Southern Company’s fuel suppliers, could limit Southern Company’s ability to operate its facilities, and thus, reduce its net income.

Southern Company may not be able to obtain adequate supply of coal, which could limit its ability to operate its facilities.

      The retail operating companies are dependent on coal for much of their electric generating capacity. Each retail operating company has coal supply contracts in place; however, there can be no assurance that the counterparties to these agreements will fulfill their obligations to supply coal to the retail operating companies. The suppliers under these agreements may experience financial or technical problems which inhibit their ability to fulfill their obligations to the retail operating companies. In addition, the suppliers under these agreements may not be required to supply coal to the retail operating companies under certain circumstances, such as in the event of a natural disaster.

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If the retail operating companies are unable to obtain their coal requirements under these contracts, the retail operating companies may be required to purchase their coal requirements at higher prices, which may not be fully recoverable through rates.

Demand for power could exceed Southern Company’s supply capacity, resulting in increased costs to Southern Company for purchasing capacity in the open market or building additional generation capabilities.

      Southern Company is currently obligated to supply power to regulated retail and wholesale customers under long-term PPAs. At peak times, the demand for power required to meet this obligation could exceed Southern Company’s available generation capacity. Market or competitive forces may require that Southern Company purchase capacity on the open market or build additional generation capabilities. Because regulators may not permit the retail operating companies to pass all of these purchase or construction costs on to their customers, the retail operating companies may not be able to recover any of these costs or may have exposure to regulatory lag associated with the time between the incurrence of costs of purchased or constructed capacity and the retail operating companies’ recovery in customers’ rates. Under Southern Power’s long-term fixed price PPAs, Southern Power would not have the ability to recover any of these costs.

Southern Company’s operating results are affected by weather conditions and may fluctuate on a seasonal and quarterly basis.

      Electric power generation is generally a seasonal business. In many parts of the country, demand for power peaks during the hot summer months, with market prices also peaking at that time. In other areas, power demand peaks during the winter. As a result, Southern Company’s overall operating results in the future may fluctuate substantially on a seasonal basis. In addition, Southern Company has historically sold less power, and consequently earned less income, when weather conditions are milder. Unusually mild weather in the future could reduce Southern Company’s revenues, net income, available cash and borrowing ability.

Risks Related to Market and Economic Volatility

Southern Company’s business is dependent on its ability to successfully access capital markets. Southern Company’s inability to access capital may limit its ability to execute its business plan or pursue improvements and make acquisitions that Southern Company may otherwise rely on for future growth.

      Southern Company relies on access to both short-term money markets and longer-term capital markets as a significant source of liquidity for capital requirements not satisfied by the cash flow from its operations. If Southern Company is not able to access capital at competitive rates, its ability to implement its business plan or pursue improvements and make acquisitions that Southern Company may otherwise rely on for future growth will be limited. Southern Company believes that it will maintain sufficient access to these financial markets based upon current credit ratings. However, certain market disruptions or a downgrade of Southern Company’s credit rating may increase its cost of borrowing or adversely affect its ability to raise capital through the issuance of securities or other borrowing arrangements. Such disruptions could include:

Southern Company is subject to risks associated with a changing economic environment, including Southern Company’s ability to obtain insurance, the financial stability of its customers and Southern Company’s ability to raise capital.

      The September 11, 2001 terrorist attacks, the continuing threat of terrorism and the related military action by the United States have affected the nation’s economy and financial markets. The insurance industry has also been disrupted by these events. The availability of insurance covering risks Southern Company and its competitors typically insure against may decrease, and the insurance that Southern Company is able to obtain

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may have higher deductibles, higher premiums and more restrictive policy terms. Any economic downturn or disruption of financial markets could constrain the capital available to Southern Company’s industry and could reduce Southern Company’s access to funding for its operations, as well as the financial stability of its customers and counterparties. These factors could adversely affect Southern Company’s subsidiaries’ ability to achieve energy sales growth, thereby decreasing Southern Company’s level of future earnings.

Construction Programs

The subsidiary companies of Southern Company are engaged in continuous construction programs to accommodate existing and estimated future loads on their respective systems. Construction expenditures during 2005 through 2007 by the retail operating companies, Southern Power and other subsidiaries are estimated as follows:

      Also included in the foregoing construction expenditure estimates are the estimates for environmental expenditures. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Capital Requirements and Contractual Obligations” of Southern Company and each retail operating company in Item 7 herein for additional information on estimated environmental expenditures.

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Estimated construction costs in 2005 are expected to be apportioned approximately as follows: (in millions)

      *These amounts include the retail operating companies and Southern Power (as detailed in the table above) as well as the amounts for the other subsidiaries. See BUSINESS — “Other Business” in Item 1 herein for additional information.

      The construction programs are subject to periodic review and revision, and actual construction costs may vary from the above estimates because of numerous factors. These factors include: changes in business conditions; acquisition of additional generating assets; revised load growth estimates; environmental regulations; changes in existing nuclear plants to meet new regulatory requirements; changes in FERC rules and transmission regulations; increasing cost of construction labor, equipment and materials; and cost of capital. In addition, there can be no assurance that costs related to capital expenditures will be fully recovered.

      Under Georgia law, Georgia Power and Savannah Electric each are required to file an Integrated Resource Plan for approval by the Georgia PSC. Under the plan rules, the Georgia PSC must pre-certify the construction of new power plants and new PPAs. See BUSINESS — “Rate Matters — Integrated Resource Planning” in Item 1 herein and Note 3 to the financial statements under “Plant McIntosh Construction Project” of Southern Company, Georgia Power and Savannah Electric and Note 2 to the financial statements of Southern Power in Item 8 herein under “Plant McIntosh Construction Project” for additional information regarding the acquisition by Georgia Power and Savannah Electric of the Plant McIntosh construction project and the withdrawal of the PPAs with Southern Power for Plant McIntosh’s capacity.

      See BUSINESS — “Regulation — Environmental Statutes and Regulations” in Item 1 herein for additional information with respect to certain existing and proposed environmental requirements and PROPERTIES — “Jointly-Owned Facilities” in Item 2 herein for additional information concerning Alabama Power’s, Georgia Power’s and Southern Power’s joint ownership of certain generating units and related facilities with certain non-affiliated utilities.

Financing Programs

See each of the registrant’s MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY in Item 7 herein, Note 6 to the financial statements of Southern Company, Alabama Power, Georgia Power, Gulf Power, Mississippi Power and Savannah Electric and Note 5 to the financial statements of Southern Power in Item 8 herein for information concerning financing programs.

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Fuel Supply

The retail operating companies’ and SEGCO’s supply of electricity is derived predominantly from coal. Southern Power’s supply of electricity is primarily fueled by natural gas. The sources of generation for the years 2002 through 2004 are shown below:

  * Less than 0.5%.
** Not applicable.

      The average costs of fuel in cents per net kilowatt-hour generated for 2002 through 2004 are shown below:

      The retail operating companies have long-term agreements in place from which they expect to receive approximately 85.7% of their coal burn requirements in 2005. These agreements cover remaining terms up to 8 years. In 2004, the weighted average sulfur content of all coal burned by the retail operating companies was 0.74% sulfur. This sulfur level, along with banked and purchased sulfur dioxide allowances, allowed the retail operating companies to remain within limits set by the Phase II acid rain requirements of the Clean Air Act. In 2004, Southern Company purchased approximately $45 million in sulfur dioxide and nitrogen oxide emission allowances. As additional environmental regulations are proposed that impact the utilization of coal, the retail operating companies’ fuel mix will be monitored to ensure that the retail operating companies remain in compliance with applicable laws and regulations. Additionally, Southern Company and the retail operating companies will continue to evaluate the need to purchase additional emission allowances, and the timing of capital expenditures for emission control equipment. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Statutes and Regulations” of Southern Company and each of the retail operating companies in Item 7 herein for information on the Clean Air Act.

      The retail operating companies, Southern Power and Southern Company GAS also have long-term agreements

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in place for their natural gas burn requirements. For 2005, the retail operating companies, Southern Power and Southern Company GAS have contracted for 103 billion cubic feet of natural gas supply. These agreements cover remaining terms up to 14 years. In addition to gas supply, the retail operating companies, Southern Power and Southern Company GAS have contracts in place for both firm gas transportation and storage. Management believes that these contracts provide sufficient natural gas supplies, transportation and storage to ensure normal operations of the Southern Company system’s natural gas generating units.

      Changes in fuel prices to the retail operating companies are generally reflected in fuel adjustment clauses contained in rate schedules. See BUSINESS — “Rate Matters — Rate Structure” in Item 1 herein for additional information.

      Alabama Power and Georgia Power have numerous contracts covering a portion of their nuclear fuel needs for uranium, conversion services, enrichment services and fuel fabrication. These contracts have varying expiration dates and most are short to medium term (less than 10 years). Management believes that sufficient capacity for nuclear fuel supplies and processing exists to preclude the impairment of normal operations of the Southern Company system’s nuclear generating units.

      Alabama Power and Georgia Power have contracts with the DOE that provide for the permanent disposal of spent nuclear fuel. The DOE failed to begin disposing of spent fuel in January 1998, as required by the contracts, and Alabama Power and Georgia Power are pursuing legal remedies against the government for breach of contract. Sufficient pool storage capacity is available at Plant Farley to maintain full-core discharge capability until the refueling outages scheduled for 2006 and 2008 for units 1 and 2, respectively. Construction of an on-site dry storage facility at Plant Farley is in progress and scheduled for operation in 2005. The onsite storage facility is expected to provide adequate spent fuel storage through 2015 for both units. Also, the facility will be able to be expanded to provide storage through 2025. Sufficient pool storage capacity for spent fuel is available at Plant Vogtle to maintain full-core discharge capability for both units into 2015. Construction of an on-site dry storage facility at Plant Vogtle is expected to begin in sufficient time to maintain pool full-core discharge capability. At Plant Hatch, an on-site dry storage facility became operational in 2000 and can be expanded to accommodate spent fuel through the life of the Plant.

      The Energy Act established a Uranium Enrichment Decontamination and Decommissioning Fund, which is funded in part by a special assessment on utilities with nuclear plants, including Alabama Power and Georgia Power. This assessment is being paid over a 15-year period ending in 2008. This fund will be used by the DOE for the decontamination and decommissioning of its nuclear fuel enrichment facilities. The law provides that utilities will recover these payments in the same manner as any other fuel expense. See Note 1 to the financial statements of Southern Company, Alabama Power and Georgia Power under the heading “Fuel Costs” in Item 8 herein for additional information.

Territory Served by the Utilities

The territory in which the retail operating companies provide electric service comprises most of the states of Alabama and Georgia together with the northwestern portion of Florida and southeastern Mississippi. In this territory there are non-affiliated electric distribution systems which obtain some or all of their power requirements either directly or indirectly from the retail operating companies. The territory has an area of approximately 120,000 square miles and an estimated population of approximately 11 million.

      Alabama Power is engaged, within the State of Alabama, in the generation and purchase of electricity and the distribution and sale of such electricity at retail in over 1,000 communities (including Anniston, Birmingham, Gadsden, Mobile, Montgomery and Tuscaloosa) and at wholesale to 15 municipally-owned electric distribution systems, 11 of which are served indirectly through sales to AMEA, and two rural distributing cooperative associations. Alabama Power also supplies steam service in downtown Birmingham. Alabama Power owns coal reserves near its Gorgas Steam Electric Generating Plant and uses the output of coal from the reserves in its generating plants. Alabama Power also sells, and cooperates with dealers in promoting the sale of, electric appliances.

      Georgia Power is engaged in the generation and purchase of electricity and the transmission, distribution and sale of such electricity within the State of Georgia at retail in over 600 communities, as well as in rural areas,

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and at wholesale currently to OPC, MEAG, Dalton and the City of Hampton.

      Gulf Power is engaged, within the northwestern portion of Florida, in the generation and purchase of electricity and the distribution and sale of such electricity at retail in 71 communities (including Pensacola, Panama City and Fort Walton Beach), as well as in rural areas, and at wholesale to a non-affiliated utility and a municipality.

      Mississippi Power is engaged in the generation and purchase of electricity and the distribution and sale of such energy within the 23 counties of southeastern Mississippi, at retail in 123 communities (including Biloxi, Gulfport, Hattiesburg, Laurel, Meridian and Pascagoula), as well as in rural areas, and at wholesale to one municipality, six rural electric distribution cooperative associations and one generating and transmitting cooperative.

      Savannah Electric is engaged, within a five-county area in eastern Georgia, in the generation and purchase of electricity and the distribution and sale of such electricity at retail.

      Through the Southern Company system power pool, the retail operating companies are also engaged in the transmission and sale of wholesale energy.

      For information relating to kilowatt-hour sales by classification for the retail operating companies, see MANAGEMENT’S DISCUSSION AND ANALYSIS — RESULTS OF OPERATIONS of each of the retail operating companies in Item 7 herein. Also, for information relating to the sources of revenues for the Southern Company system, each of the retail operating companies and Southern Power, reference is made to Item 6 herein.

      A portion of the area served by the retail operating companies adjoins the area served by TVA and its municipal and cooperative distributors. An Act of Congress limits the distribution of TVA power, unless otherwise authorized by Congress, to specified areas or customers which generally were those served on July 1, 1957.

      The RUS has authority to make loans to cooperative associations or corporations to enable them to provide electric service to customers in rural sections of the country. There are 71 electric cooperative organizations operating in the territory in which the retail operating companies provide electric service at retail or wholesale.

      One of these, AEC, is a generating and transmitting cooperative selling power to several distributing cooperatives, municipal systems and other customers in south Alabama and northwest Florida. AEC owns generating units with approximately 1,776 megawatts of nameplate capacity, including an undivided 8.16% ownership interest in Alabama Power’s Plant Miller Units 1 and 2. AEC’s facilities were financed with RUS loans secured by long-term contracts requiring distributing cooperatives to take their requirements from AEC to the extent such energy is available. Two of the 14 distributing cooperatives operating in Alabama Power’s service territory obtain a portion of their power requirements directly from Alabama Power.

      Four electric cooperative associations, financed by the RUS, operate within Gulf Power’s service area. These cooperatives purchase their full requirements from AEC and SEPA (a federal power marketing agency). A non-affiliated utility also operates within Gulf Power’s service area and purchases its full requirements from Gulf Power.

      Alabama Power and Gulf Power have entered into separate agreements with AEC involving interconnection between their respective systems. The delivery of capacity and energy from AEC to certain distributing cooperatives in the service areas of Alabama Power and Gulf Power is governed by the Southern Company/AEC Network Transmission Service Agreement. The rates for this service to AEC are based on the negotiated agreement on file with the FERC. See PROPERTIES — “Jointly-Owned Facilities” in Item 2 herein for details of Alabama Power’s joint-ownership with AEC of a portion of Plant Miller.

      Mississippi Power has an interchange agreement with SMEPA, a generating and transmitting cooperative, pursuant to which various services are provided, including the furnishing of protective capacity by Mississippi Power to SMEPA.

      There are 43 electric cooperative organizations operating in, or in areas adjoining, territory in the State of Georgia in which Georgia Power provides electric service at retail or wholesale. In January 2005, three of these organizations began obtaining their power from

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TVA, one from Southern Power under a 15-year agreement and one from other sources. OPC has a wholesale power contract with the remaining 38 of these cooperative organizations. OPC and these cooperative organizations utilize self-owned generation, some of which is acquired and jointly-owned with Georgia Power, megawatt capacity purchases from Georgia Power under power supply agreements and other arrangements to meet their power supply obligations. Georgia Power, OPC, and Georgia Systems Operations Corporation have entered into a new control area compact agreement that will replace current coordination service agreements among the parties in 2005 pending acceptance by the FERC.

      Pursuant to an agreement entered into in April 1999, OPC will purchase 250 megawatts of capacity from Georgia Power through March 2006. In April 2006, AEC will start purchasing such capacity for a 10-year term. In January 2005, 30 electric cooperative organizations served by OPC began purchasing a total of 700 megawatts of capacity from Georgia Power under individual contracts for 10-year terms. Also, on January 1, 2005, one of the electric cooperatives began purchasing 25 megawatts of peaking capacity from Georgia Power under a 10-year contract. Another of the electric cooperatives will purchase 50 megawatts and 75 megawatts of peaking capacity from Georgia Power beginning April 1, 2006 and June 1, 2010, respectively. See PROPERTIES — “Jointly-Owned Facilities” in Item 2 herein for additional information.

      There are 65 municipally-owned electric distribution systems operating in the territory in which the retail operating companies provide electric service at retail or wholesale.

      AMEA was organized under an act of the Alabama legislature and is comprised of 11 municipalities. In October 1991, Alabama Power entered into a power sales contract with AMEA entitling AMEA to scheduled amounts of additional capacity (up to a maximum 80 megawatts) for a period of 15 years. Under the terms of the contract, Alabama Power received payments from AMEA representing the net present value of the revenues associated with the respective capacity entitlements. See Note 6 to the financial statements of Alabama Power under “First Mortgage Bonds” in Item 8 herein for further information on this contract.

      Forty-eight municipally-owned electric distribution systems and one county-owned system receive their requirements through MEAG, which was established by a Georgia state statute in 1975. MEAG serves these requirements from self-owned generation facilities, some of which are acquired and jointly-owned with Georgia Power, power purchased from Georgia Power and purchases from other resources. In 1997, a pseudo scheduling and services agreement was implemented between Georgia Power and MEAG. Since 1977, Dalton has filled its requirements from self-owned generation facilities, some of which are acquired and jointly-owned with Georgia Power, and through purchases from Georgia Power pursuant to their partial requirements tariff. Beginning January 1, 2003, Dalton entered into a power supply agreement pursuant to which it will purchase 134 megawatts from Georgia Power for a 15-year term. In addition, another municipally-owned electric distribution system’s full requirements are served under a market-based contract by Georgia Power. See PROPERTIES — “Jointly-Owned Facilities” in Item 2 herein for additional information.

      Georgia Power has entered into substantially similar agreements with Georgia Transmission Corporation (formerly OPC’s transmission division), MEAG and Dalton providing for the establishment of an integrated transmission system to carry the power and energy of each. The agreements require an investment by each party in the integrated transmission system in proportion to its respective share of the aggregate system load. See PROPERTIES — “Jointly-Owned Facilities” in Item 2 herein for additional information.

      See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Other Matters” of Gulf Power and MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Power Sales Agreements” of Southern Power in Item 8 herein for information concerning certain PPAs entered into during 2004.

      SCS, acting on behalf of the retail operating companies, also has a contract with SEPA providing for the use of those companies’ facilities at government expense to deliver to certain cooperatives and municipalities, entitled by federal statute to preference in the purchase of power from SEPA, quantities of power equivalent to the amounts of power allocated to them by SEPA from certain United States government hydroelectric projects.

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      The retail service rights of all electric suppliers in the State of Georgia are regulated by the 1973 State Territorial Electric Service Act. Pursuant to the provisions of this Act, all areas within existing municipal limits were assigned to the primary electric supplier therein (451 municipalities, including Atlanta, Columbus, Macon, Augusta, Athens, Rome and Valdosta, to Georgia Power; 115 to electric cooperatives; and 50 to publicly-owned systems). Areas outside of such municipal limits were either to be assigned or to be declared open for customer choice of supplier by action of the Georgia PSC pursuant to standards set forth in the Act. Consistent with such standards, the Georgia PSC has assigned substantially all of the land area in the state to a supplier. Notwithstanding such assignments, the Act provides that any new customer locating outside of 1973 municipal limits and having a connected load of at least 900 kilowatts may receive electric service from the supplier of its choice. See BUSINESS — “Competition” in Item 1 herein for additional information.

      Under and subject to the provisions of its franchises and concessions and the 1973 State Territorial Electric Service Act, Savannah Electric has the full but nonexclusive right to serve the City of Savannah, the Towns of Bloomingdale, Pooler, Garden City, Guyton, Newington, Oliver, Port Wentworth, Rincon, Tybee Island, Springfield, Thunderbolt and Vernonburg, and in conjunction with a secondary supplier, the Town of Richmond Hill. In addition, Savannah Electric has been assigned certain unincorporated areas in Chatham, Effingham, Bryan, Bulloch and Screven Counties by the Georgia PSC. See BUSINESS — “Competition” in Item 1 herein for additional information.

      Pursuant to the 1956 Utility Act, the Mississippi PSC issued “Grandfather Certificates” of public convenience and necessity to Mississippi Power and to six distribution rural cooperatives operating in southeastern Mississippi, then served in whole or in part by Mississippi Power, authorizing them to distribute electricity in certain specified geographically described areas of the state. The six cooperatives serve approximately 375,000 retail customers in a certificated area of approximately 10,300 square miles. In areas included in a “Grandfather Certificate,” the utility holding such certificate may, without further certification, extend its lines up to five miles; other extensions within that area by such utility, or by other utilities, may not be made except upon a showing of, and a grant of a certificate of, public convenience and necessity. Areas included in such a certificate which are subsequently annexed to municipalities may continue to be served by the holder of the certificate, irrespective of whether it has a franchise in the annexing municipality. On the other hand, the holder of the municipal franchise may not extend service into such newly annexed area without authorization by the Mississippi PSC.

Competition

      The electric utility industry in the United States is continuing to evolve as a result of regulatory and competitive factors. Among the early primary agents of change was the Energy Act. The Energy Act allowed IPPs to access a utility’s transmission network in order to sell electricity to other utilities.

      Alabama Power currently has cogeneration contracts in effect with 11 industrial customers. Under the terms of these contracts, Alabama Power purchases excess generation of such companies. During 2004, Alabama Power purchased approximately 178 million kilowatt-hours from such companies at a cost of $5.2 million.

      Georgia Power currently has contracts in effect with nine small power producers whereby Georgia Power purchases their excess generation. During 2004, Georgia Power purchased 10 million kilowatt-hours from such companies at a cost of $0.6 million. Georgia Power has PPAs for electricity with two cogeneration facilities. Payments are subject to reductions for failure to meet minimum capacity output. During 2004, Georgia Power purchased 79 million kilowatt-hours at a cost of $53 million from these facilities. See Note 7 to the financial statements for Georgia Power herein under “Purchased Power Commitments” in Item 8 for additional information regarding purchased power commitments.

      Gulf Power currently has agreements in effect with various industrial, commercial and qualifying facilities pursuant to which Gulf Power purchases “as available” energy from customer-owned generation. During 2004, Gulf Power purchased 31 million kilowatt-hours from such companies for $591,000.

      Mississippi Power currently has a cogeneration agreement in effect with one of its industrial customers. Under the terms of this contract, Mississippi Power purchases any excess generation. During 2004,

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Mississippi Power purchased approximately 12 million kilowatt-hours of excess generation at a cost of $300,000.

      During 2004, Savannah Electric purchased energy from six customer-owned generating facilities. Five of the six provide only excess energy to Savannah Electric and are paid Savannah Electric’s avoided energy cost. These five customers make no capacity commitment and are not dispatched by Savannah Electric. Savannah Electric does have a contract for five megawatts of dispatchable capacity and energy with one customer. During 2004, Savannah Electric purchased a total of 34 million kilowatt-hours from the six suppliers at a cost of approximately $1.3 million.

      The competition for retail energy sales among competing suppliers of energy is influenced by various factors, including price, availability, technological advancements and reliability. These factors are, in turn, affected by, among other influences, regulatory, political and environmental considerations, taxation and supply.

      The retail operating companies have experienced, and expect to continue to experience, competition in their respective retail service territories in varying degrees as the result of self-generation (as described above) and fuel switching by customers and other factors. See also BUSINESS — “Territory Served by the Utilities” in Item 1 herein for additional information concerning suppliers of electricity operating within or near the areas served at retail by the retail operating companies.

Regulation

State Commissions

The retail operating companies are subject to the jurisdiction of their respective state PSCs, which have broad powers of supervision and regulation over public utilities operating in the respective states, including their rates, service regulations, sales of securities (except for the Mississippi PSC) and, in the cases of the Georgia PSC and Mississippi PSC, in part, retail service territories. See BUSINESS — “Territory Served by the Utilities” and “Rate Matters” in Item 1 herein for additional information.

Holding Company Act

Southern Company is registered as a holding company under the Holding Company Act, and it and its subsidiary companies are subject to the regulatory provisions of said Act, including provisions relating to the issuance of securities, sales and acquisitions of securities and utility assets, services performed by SCS and Southern Nuclear and the activities of certain of Southern Company’s other subsidiaries.

      While various proposals have been introduced in Congress regarding the Holding Company Act, the prospects for legislative reform or repeal are uncertain at this time.

Federal Power Act

The Federal Power Act subjects the retail operating companies, Southern Power and SEGCO to regulation by the FERC as companies engaged in the transmission or sale at wholesale of electric energy in interstate commerce, including regulation of accounting policies and practices.

      Alabama Power and Georgia Power are also subject to the provisions of the Federal Power Act or the earlier Federal Water Power Act applicable to licensees with respect to their hydroelectric developments. Among the hydroelectric projects subject to licensing by the FERC are 14 existing Alabama Power generating stations having an aggregate installed capacity of 1,662,400 kilowatts and 18 existing Georgia Power generating stations having an aggregate installed capacity of 1,074,696 kilowatts.

      In December 2002, Georgia Power filed a relicensing application for the Middle Chattahoochee Project with the FERC. On December 27, 2004, the FERC issued a new 30-year license for the Middle Chattahoochee Project. This project consists of the Goat Rock, Oliver and North Highlands facilities. In 2003, Georgia Power started the relicensing process for the Morgan Falls project and is currently working on developing study plans for the facility with license participants. Alabama Power initiated the relicensing process in 2002 for its seven projects on the Coosa River (Weiss, Henry, Logan Martin, Lay, Mitchell, Jordan and Bouldin) and the Smith and Bankhead projects on the Warrior River. The FERC licenses for all of these eight projects expire in 2007.

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      Georgia Power and OPC also have a license, expiring in 2027, for the Rocky Mountain Plant, a pure pumped storage facility of 847,800 kilowatt capacity which began commercial operation in 1995. See PROPERTIES — “Jointly-Owned Facilities” in Item 2 herein for additional information.

      Licenses for all projects, excluding those discussed above, expire in the period 2007-2033 in the case of Alabama Power’s projects and in the period 2005-2039 in the case of Georgia Power’s projects.

      Upon or after the expiration of each license, the United States Government, by act of Congress, may take over the project or the FERC may relicense the project either to the original licensee or to a new licensee. In the event of takeover or relicensing to another, the original licensee is to be compensated in accordance with the provisions of the Federal Power Act, such compensation to reflect the net investment of the licensee in the project, not in excess of the fair value of the property taken, plus reasonable damages to other property of the licensee resulting from the severance therefrom of the property taken.

Atomic Energy Act of 1954

Alabama Power, Georgia Power and Southern Nuclear are subject to the provisions of the Atomic Energy Act of 1954, as amended, which vests jurisdiction in the NRC over the construction and operation of nuclear reactors, particularly with regard to certain public health and safety and antitrust matters. The National Environmental Policy Act has been construed to expand the jurisdiction of the NRC to consider the environmental impact of a facility licensed under the Atomic Energy Act of 1954, as amended.

      NRC operating licenses currently expire in June 2017 and March 2021 for Plant Farley units 1 and 2, respectively, and in January 2027 and February 2029 for Plant Vogtle units 1 and 2, respectively. In January 2002, the NRC granted Georgia Power a 20-year extension of the licenses for both units at Plant Hatch which permits the operation of units 1 and 2 until 2034 and 2038, respectively. Alabama Power filed an application with the NRC in September 2003 to extend the operating license for Plant Farley for an additional 20 years.

      See Notes 1 and 9 to the financial statements of Southern Company, Alabama Power and Georgia Power in Item 8 herein for information on nuclear decommissioning costs and nuclear insurance.

FERC Matters

See Southern Company’s, Alabama Power’s, Georgia Power’s, Gulf Power’s, Mississippi Power’s, Savannah Electric’s and Southern Power’s, MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “FERC and State PSC Matters,” “FERC and Alabama PSC Matters,” “FERC and Georgia PSC Matters,” “FERC and Florida PSC Matters,” “FERC and Mississippi PSC Matters,” “FERC and Georgia PSC Matters” and “FERC Matters” in Item 7 herein for information on matters regarding the FERC.

Environmental Statutes and Regulations

Southern Company’s operations are subject to extensive regulation by state and federal environmental agencies under a variety of statutes and regulations governing environmental media, including air, water and land resources. Compliance with these environmental requirements involves significant costs, a major portion of which is expected to be recovered through existing ratemaking provisions. There is no assurance, however, that all such costs will, in fact, be recovered.

      Compliance with the federal Clean Air Act and resulting regulations has been, and will continue to be, a significant focus for Southern Company. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters” of Southern Company and each of the retail operating companies in Item 7 herein for additional information about the Clean Air Act and other environmental issues, including the litigation brought under the New Source Review provisions of the Clean Air Act.

      Additionally, each retail operating company and SEGCO has incurred costs for environmental remediation of various sites. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL - “Environmental Remediation Reserves” of Southern Company and each of the retail operating companies in Item 7 herein for

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information regarding environmental remediation efforts. Also, see Note 3 to the financial statements of Southern Company, Georgia Power, Gulf Power and Mississippi Power in Item 8 herein under “Environmental Matters — Environmental Remediation,” for information regarding the identification of sites that may require environmental remediation.

      The retail operating companies, Southern Power and SEGCO are unable to predict at this time what additional steps they may be required to take as a result of the implementation of existing or future quality control requirements for air, water and hazardous or toxic materials, but such steps could adversely affect system operations and result in substantial additional costs.

      The outcome of the matters mentioned above under “Regulation” cannot now be determined, except that these developments may result in delays in obtaining appropriate licenses for generating facilities, increased construction and operating costs or reduced generation, the nature and extent of which, while not determinable at this time, could be substantial.

Rate Matters

Rate Structure

The rates and service regulations of the retail operating companies are uniform for each class of service throughout their respective service areas. Rates for residential electric service are generally of the block type based upon kilowatt-hours used and include minimum charges.

      Residential and other rates contain separate customer charges. Rates for commercial service are presently of the block type and, for large customers, the billing demand is generally used to determine capacity and minimum bill charges. These large customers’ rates are generally based upon usage by the customer and include rates with special features to encourage off-peak usage. Additionally, the retail operating companies are allowed by their respective PSCs to negotiate the terms and compensation of service to large customers. Such terms and compensation of service, however, are subject to final PSC approval. Alabama Power, Georgia Power, Mississippi Power and Savannah Electric are allowed by state law to recover fuel and net purchased energy costs through fuel cost recovery provisions which are adjusted to reflect increases or decreases in such costs as needed. Gulf Power also recovers from retail customers costs of fuel, net purchased power, energy conservation and environmental compliance through provisions approved by the Florida PSC which are adjusted annually to reflect increases or decreases in such costs. Revenues are adjusted for differences between recoverable costs and amounts actually recovered in current rates.

      See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL in Item 7 and to Note 3 to the financial statements in Item 8 herein for Alabama Power, Georgia Power, Gulf Power, Mississippi Power and Savannah Electric for a discussion of rate matters.

Integrated Resource Planning

Georgia Power and Savannah Electric must file IRPs with the Georgia PSC that specify how each intends to meet the future electrical needs of its customers through a combination of demand-side and supply-side resources. The Georgia PSC must certify these new resources. Once certified, all prudently incurred constructions costs and purchase power costs will be recoverable through rates.

      In July 2001, the Georgia PSC approved Georgia Power’s certification request for approximately 1,800 megawatts of purchased power and 12 megawatts of upgraded hydro generation. This certification request included a seven-year PPA with Southern Power for two gas-fired, combined cycle units at Plant Franklin. The purchase of the full 570 megawatts from the first unit began in 2003 with the purchase of approximately 250 megawatts beginning earlier in June 2002. The purchase of the full 610 megawatts from the second unit began in 2004 with the purchase of approximately 300 megawatts beginning earlier in June 2003. Also, an upgrade of 12 megawatts was approved for the existing Goat Rock hydro units 1 and 2. Additionally, this certification included approval of a 15-year PPA with Southern Power for 615 megawatts of gas-fired combined cycle generation at Plant Harris in Alabama.

      In December 2002, the Georgia PSC certified the Duke Energy (Murray) generating facility. The Duke Energy (Murray) PPA provides for the purchase by Georgia Power of the full 620 megawatts of output for seven years beginning in June 2005.

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      On January 30, 2004, Georgia Power and Savannah Electric filed the 2004 IRP with the Georgia PSC and received Georgia PSC approval of the 2004 IRP on July 9, 2004. Through the approval of the 2004 IRP, Georgia Power de-certified the Atkinson combustion turbine units 5A and 5B totaling approximately 80 megawatts of capacity. Georgia Power and Savannah Electric will issue an RFP in July 2005 for approximately 1,200 megawatts to meet their future supply-side capacity needs for 2009 and beyond. Additionally, Georgia Power and Savannah Electric will each continue a residential load management program which was certified by the Georgia PSC for up to 40 megawatts of equivalent supply-side capacity. Georgia Power will continue to utilize approximately 8 megawatts of capacity from existing qualifying facilities under firm contracts and continue to add additional resources as ordered by the Georgia PSC.

      In May 2004, the Georgia PSC ordered Georgia Power and Savannah Electric to purchase the McIntosh combined cycle generating facility from Southern Power and place it into their respective rate bases. The McIntosh resource was previously certified as a PPA by the Georgia PSC in the 2002 supply-side certification. The McIntosh units will produce a combined 1,240 megawatts of which Georgia Power’s portion is 1,040 megawatts and Savannah Electric’s portion is 200 megawatts. This new generation is expected to be available by June 2005. See Note 3 to the financial statements of Southern Company, Georgia Power and Savannah Electric under “Plant McIntosh Construction Project” in Item 8 herein for additional information.

Environmental Cost Recovery Plans

On October 5, 2004, the Alabama PSC approved a specific rate mechanism for the recovery of Alabama Power’s retail costs associated with environmental laws, regulations or other such mandates. The rate mechanism began operation in January 2005 and provides for the recovery of these costs pursuant to a factor that will be calculated annually. Environmental costs to be recovered include operation and maintenance expense, depreciation and a return on invested capital. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNING POTENTIAL — “FERC and State PSC Matters” and “FERC and Alabama PSC Matters,” respectively, in Item 7 herein and Note 3 to the financial statements of Southern Company and Alabama Power in Item 8 herein for a discussion on Alabama PSC rate matters.

      The Florida Legislature has adopted legislation for an Environmental Cost Recovery Clause, which allows Gulf Power to petition the Florida PSC for recovery of prudent environmental compliance costs that are not being recovered through base rates or any other recovery mechanism. Such environmental costs include operation and maintenance expense, emission allowance expense, depreciation and a return on invested capital.

      This legislation was amended in 2002 to allow recovery of costs incurred as a result of an agreement between Gulf Power and the Florida Department of Environmental Protection for the purpose of ensuring compliance with ozone ambient air quality standards adopted by the EPA. See Note 3 to the financial statements of Gulf Power in Item 8 herein under “Environmental Remediation” for additional information.

      In 1992, the Mississippi PSC approved Mississippi Power’s Environmental Compliance Overview Plan (ECO Plan). The ECO Plan establishes procedures to facilitate the Mississippi PSC’s overview of Mississippi Power’s environmental strategy and provides for recovery of costs (including costs of capital associated with environmental projects approved by the Mississippi PSC). Under the ECO Plan, any increase in the annual revenue requirement is limited to two percent of retail revenues. However, the ECO Plan also provides for carryover of any amount over the two percent limit into the next year’s revenue requirement. Mississippi Power conducts studies, when possible, to determine the extent of any required environmental remediation. Should such remediation be determined to be probable, reasonable estimates of costs to clean up such sites are developed and recognized in the financial statements. Mississippi Power recovers such costs under the ECO Plan as they are incurred, as provided for in Mississippi Power’s 1994 ECO Plan order. Mississippi Power filed its 2005 ECO Plan in January 2005, which, if approved as filed, will result in an increase in customer prices. See Note 3 to the financial statements of Mississippi Power under “Environmental Compliance Overview Plan” for additional information.

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Employee Relations

The Southern Company system had a total of 25,648 employees on its payroll at December 31, 2004.

* Southern Power has no employees. Southern Power has agreements with SCS and the retail operating companies whereby employee services are rendered at cost.

      The retail operating companies have separate agreements with local unions of the IBEW generally covering wages, working conditions and procedures for handling grievances and arbitration. These agreements apply with certain exceptions to operating, maintenance and construction employees.

      Alabama Power has agreements with the IBEW on a five-year contract extending to August 15, 2009. Upon notice given at least 60 days prior to that date, negotiations may be initiated with respect to agreement terms to be effective after such date.

      Georgia Power has an agreement with the IBEW covering wages and working conditions, which is in effect through June 30, 2005. Negotiations are expected to begin in early May 2005 for a new agreement which is expected to be in effect for the next three years beginning July 1, 2005.

      Gulf Power has an agreement with the IBEW covering wages and working conditions, which is in effect through August 15, 2005. Negotiations for a new agreement are scheduled to begin June 6, 2005. The term of the new agreement is subject to negotiation.

      Mississippi Power has an agreement with the IBEW on a four-year contract extending to August 16, 2006.

      Savannah Electric has three-year labor agreements with the IBEW and the Office and Professional Employees International Union that expire April 15, 2006 and December 1, 2006, respectively.

      Southern Nuclear has agreements with the IBEW on a five-year contract extending to August 15, 2006 for Plant Farley, and a three-year contract extending to June 30, 2005 for Plants Hatch and Vogtle. Upon notice given at least 60 days prior to these dates, negotiations may be initiated with respect to agreement terms to be effective after such dates.

      The agreements also subject the terms of the pension plans for the companies discussed above to collective bargaining with the unions at either a five-year or a 10-year cycle, depending upon union and company actions.

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Item 2. PROPERTIES

Electric Properties – The Electric Utilities

The retail operating companies, Southern Power and SEGCO, at December 31, 2004, owned and/or operated 34 hydroelectric generating stations, 32 fossil fuel generating stations, three nuclear generating stations and 10 combined cycle/cogeneration stations. The amounts of capacity for each company are shown in the table below.

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units of the retail operating companies, Southern Power and SEGCO are owned in fee by the respective companies. It is the opinion of management of each such company that its operating properties are adequately maintained and are substantially in good operating condition.

      Mississippi Power owns a 79-mile length of 500-kilovolt transmission line which is leased to Entergy Gulf States. The line, completed in 1984, extends from Plant Daniel to the Louisiana state line. Entergy Gulf States is paying a use fee over a 40-year period covering all expenses and the amortization of the original $57 million cost of the line. At December 31, 2004, the unamortized portion of this cost was approximately $26.2 million.

      The all-time maximum demand on the retail operating companies, Southern Power and SEGCO was 34,414,100 kilowatts and occurred on July 14, 2004. This amount excludes demand served by capacity retained by MEAG and Dalton and excludes demand associated with power purchased from OPC and SEPA by its preference customers. The reserve margin for the retail operating companies, Southern Power and SEGCO at that time was 20.2%. See SELECTED FINANCIAL DATA in Item 6 herein for additional information on peak demands.

Jointly-Owned Facilities

Alabama Power, Georgia Power and Southern Power have undivided interests in certain generating plants and other related facilities to or from non-affiliated parties. The percentages of ownership are as follows:

      Alabama Power and Georgia Power have contracted to operate and maintain the respective units in which each has an interest (other than Rocky Mountain and Intercession City) as agent for the joint owners. SCS provides operation and maintenance services for Plant Stanton A.

      In addition, Georgia Power has commitments regarding a portion of a 5 percent interest in Plant Vogtle owned by MEAG that are in effect until the later of retirement of the plant or the latest stated maturity date of MEAG’s bonds issued to finance such ownership interest. The payments for capacity are required whether any capacity is available. The energy cost is a function of each unit’s variable operating costs. Except for the portion of the capacity payments related to the Georgia PSC’s disallowances of Plant Vogtle costs, the cost of such capacity and energy is included in purchased power from non-affiliates in Georgia Power’s Statements of Income in Item 8 herein.

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Titles to Property

The retail operating companies’, Southern Power’s and SEGCO’s interests in the principal plants (other than certain pollution control facilities, one small hydroelectric generating station leased by Georgia Power, combined cycle units at Plant Daniel leased by Mississippi Power and the land on which five combustion turbine generators of Mississippi Power are located, which is held by easement) and other important units of the respective companies are owned in fee by such companies, subject only to the liens of applicable mortgage indentures of Alabama Power, Gulf Power, Mississippi Power and Savannah Electric, to second liens pursuant to pollution control bonds of Gulf Power and to excepted encumbrances as defined therein. See Note 6 to the financial statements of Southern Company, Alabama Power, Gulf Power, Mississippi Power and Savannah Electric under “Assets Subject to Lien” and Note 7 to the financial statements of Mississippi Power under “Operating Leases — Plant Daniel Combined Cycle Generating Units” in Item 8 herein for additional information. The retail operating companies own the fee interests in certain of their principal plants as tenants in common. See PROPERTIES — “Jointly-Owned Facilities” in Item 2 herein for additional information. Properties such as electric transmission and distribution lines and steam heating mains are constructed principally on rights-of-way which are maintained under franchise or are held by easement only. A substantial portion of lands submerged by reservoirs is held under flood right easements.

Item 3. LEGAL PROCEEDINGS

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See Note 3 to each registrant’s financial statements in Item 8 herein for descriptions of additional legal and administrative proceedings discussed therein.

Item 4. SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS.

      None.

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EXECUTIVE OFFICERS OF SOUTHERN COMPANY

(Identification of executive officers of Southern Company is inserted in Part I in accordance with Regulation S-K, Item 401(b), Instruction 3.) The ages of the officers set forth below are as of December 31, 2004.

David M. Ratcliffe
Chairman, President, Chief Executive Officer and Director
Age 56
Elected in 1999. President since April 2004; Chairman and Chief Executive Officer since July 2004. Previously served as Chief Executive Officer of Georgia Power from June 1999 to April 2004; and President of Georgia Power from June 1999 to December 2003.

Dwight H. Evans
Executive Vice President
Age 56
Elected in 2001. Executive Vice President since May 2001. Previously served as President and Chief Executive Officer of Mississippi Power from March 1995 to May 2001.

Thomas A. Fanning
Executive Vice President, Chief Financial Officer and Treasurer
Age 47
Elected in 2003. Executive Vice President, Chief Financial Officer and Treasurer since April 2003. Previously served as President, Chief Executive Officer and Director of Gulf Power from 2002 to April 2003; and Executive Vice President, Treasurer and Chief Financial Officer of Georgia Power from 1999 to 2002.

Michael D. Garrett
Executive Vice President
Age 55
Elected in 2004. Executive Vice President since January 1, 2004. He also serves as President and Director of Georgia Power since January 1, 2004 and Chief Executive Officer of Georgia Power since April 2004. Previously served as President, Chief Executive Officer and Director of Mississippi Power from 2001 to 2003; Executive Vice President — Customer Service of Alabama Power from January 2000 to May 2001; and Executive Vice President of External Affairs of Alabama Power from March 1998 to January 2000.

Leonard J. Haynes
Executive Vice President and Chief Marketing Officer
Age 54
Elected in 2001. Executive Vice President and Chief Marketing Officer since May 2001. Previously served as Senior Vice President of Georgia Power from October 1998 to May 2001.

G. Edison Holland, Jr.
Executive Vice President
Age 52
Elected in 2001. Executive Vice President since 2001. Previously served as President and Chief Executive Officer of Savannah Electric from 1997 until 2001.

Charles D. McCrary
Executive Vice President
Age 53
Elected in 1998. Executive Vice President of Southern Company since February 2002; President and Chief Executive Officer of Alabama Power since October 2001. Previously served as President and Chief Operating Officer of Alabama Power from April 2001 to October 2001; and Vice President of Southern Company from February 1998 to April 2001.

W. Paul Bowers (1)
Executive Vice President of SCS and President and Chief Executive Officer of Southern Power.
Age 48
Elected in 2001. Executive Vice President of SCS and President and Chief Executive Officer of Southern Power since May 2001. Previously served as Senior Vice President and Chief Marketing Officer of Southern Company from March 2000 to May 2001; and President and Chief Executive Officer of Western Power Distribution and Southwestern Electricity plc, a subsidiary of Mirant located in Bristol, England, from December 1998 to 2000.

J. Barnie Beasley
President and Chief Executive Officer of Southern Nuclear.
Age 53
Elected in 2004. President and Chief Executive Officer of Southern Nuclear since September 2004. Previously served as Executive Vice President of Southern Nuclear from January 2004 to September 2004; and Vice President from July 1998 through December 2003.

(1) Mr. Bowers has resigned as President and Chief Executive Officer of Southern Power, effective March 17, 2005.

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      The officers of Southern Company were elected for a term running from the first meeting of the directors following the last annual meeting (May 26, 2004) for one year until the first board meeting after the next annual meeting or until their successors are elected and have qualified.

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EXECUTIVE OFFICERS OF ALABAMA POWER

(Identification of executive officers of Alabama Power is inserted in Part I in accordance with Regulation S-K, Item 401(b), Instruction 3.)
The ages of the officers set forth below are as of December 31, 2004.

Charles D. McCrary
President, Chief Executive Officer and Director
Age 53
Elected in 2001. President, Chief Executive Officer and Director since October 2001; Executive Vice President of Southern Company since February 2002. Previously served as President and Chief Operating Officer of Alabama Power from April 2001 to October 2001; and Vice President of Southern Company from February 1998 to April 2001.

Art P. Beattie
Executive Vice President, Chief Financial Officer and Treasurer
Age 50
Elected in 2004. Elected Executive Vice President, Chief Financial Officer and Treasurer in November 2004, effective February 1, 2005. Previously served as Vice President and Comptroller of Alabama Power from 1998 to February 1, 2005.

C. Alan Martin
Executive Vice President
Age 56
Elected in 1999. Executive Vice President of the Customer Service Organization since 2001. Previously served as Executive Vice President of External Affairs from January 2000 to April 2001.

Steven R. Spencer
Executive Vice President
Age 49
Elected in 2001. Executive Vice President of External Affairs since 2001. Previously served as Senior Vice President of External Affairs from July 2000 to April 2001; and Vice President of Southern Company’s External Affairs organization from 1998 to 2000.

Jerry L. Stewart
Senior Vice President
Age 55
Elected in 1999. Senior Vice President of Fossil and Hydro Generation since 1999.

      The officers of Alabama Power were elected for a term running from the last annual meeting of the directors (April 23, 2004) for one year until the next annual meeting or until their successors are elected and have qualified, except for Mr. Beattie whose election was effective on the date indicated.

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EXECUTIVE OFFICERS OF GEORGIA POWER

(Identification of executive officers of Georgia Power is inserted in Part I in accordance with Regulation S-K, Item 401(b), Instruction 3.)
The ages of the officers set forth below are as of December 31, 2004.

Michael D. Garrett
Chief Executive Officer, President and Director
Age 55
Elected in 2003. Chief Executive Officer since April 2004; President and Director since January 1, 2004. Previously served as President, Chief Executive Officer and Director of Mississippi Power from 2001 to 2003; Executive Vice President — Customer Service of Alabama Power from January 2000 to May 2001; and Executive Vice President of External Affairs of Alabama Power from March 1998 to January 2000.

William C. Archer, III
Executive Vice President
Age 56
Elected in 1995. Executive Vice President of External Affairs since 1995.

Mickey A. Brown
Executive Vice President
Age 57
Elected in 2001. Executive Vice President of the Customer Service Organization since January 10, 2005. Previously served as Senior Vice President of Distribution from 2001 to 2005; Vice President, Distribution from 2000 to 2001; and Vice President, Northern Region from 1993 to 2000.

C. B. Harreld (1)
Executive Vice President, Chief Financial Officer, Treasurer and Assistant Secretary
Age 60
Elected in 2003. Executive Vice President, Chief Financial Officer and Treasurer since 2003. Previously served as Senior Vice President of Finance, SCS from 2002 to 2003; Chief Financial Officer and Comptroller of Southern Company Generation and Energy Marketing from 2001 to 2002; Chief Financial Officer of Mirant — Europe from 2000 to 2001; and Vice President and Controller, Southern Energy, Inc. from 1999 to 2000.

Cliff S. Thrasher (2)
Executive Vice President, Chief Financial Officer and Treasurer
Age 55
Elected in 2005. Currently serves as Senior Vice President, Comptroller and Chief Financial Officer of Southern Power since November 2002 and Vice President of SCS since June 2002. Previously served as Vice President, Comptroller and Chief Financial Officer of Southern Power from June 2002 to November 2002; and Vice President, Comptroller and Chief Accounting Officer of Georgia Power from September 1995 to June 2002.

Judy M. Anderson
Senior Vice President
Age 56
Elected in 2001. Senior Vice President of Charitable Giving since 2001. Previously served as Vice President and Corporate Secretary of Georgia Power from 1989 to 2001.

Richard L. Holmes
Senior Vice President
Age 53
Elected in 2003. Senior Vice President of Metro Division, Diversity and Corporate Relations since February 2005. Previously served as Senior Vice President of Corporate Services from 2003 to 2005. Vice President of Corporate Services from 2002 to 2003; Vice President of Region Operations from 2000 to 2002; and Assistant to the President and Chief Executive Officer from 1999 to 2000.

Douglas E. Jones
Senior Vice President
Age 46
Elected in 2005. Senior Vice President since January 10, 2005. Previously served as Executive Vice President of Southern Power from January 2004 to January 2005; Senior Vice President, Southern Company Energy Marketing from December 2001 to January 2004; and Vice President, Southern Company Wholesale Energy from December 1998 to 2001.

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James H. Miller, III
Senior Vice President
Age 55
Elected in 2004. Senior Vice President and General Counsel since March 2004. Previously served as Vice President and Associate General Counsel for SCS and Senior Vice President, General Counsel and Assistant Secretary of Southern Power from 2001 to 2004; and Senior Vice President, Alabama Power - Birmingham Division from 1999 to 2001.

Leslie R. Sibert
Vice President
Age 42
Elected in 2001. Vice President, Transmission since 2001. Previously served as Decatur Region Manager from 1999 to 2001.

Christopher C. Womack
Senior Vice President
Age 46
Elected in 2001. Senior Vice President of Fossil and Hydro since 2001. Previously served as Vice President and Chief People Officer of Southern Company from 1998 to 2001.

(1) Mr. Harreld was elected Executive Vice President of SCS and Chief Financial Officer of Southern Company’s transmission business unit, effective March 17, 2005 and resigned from Georgia Power effective as of such date.

(2) Mr. Thrasher was elected Executive Vice President, Chief Financial Officer and Treasurer, effective March 17, 2005.

      The officers of Georgia Power were elected for a term running from the last annual meeting of the directors (May 19, 2004) for one year until the next annual meeting or until their successors are elected and have qualified, except for Mr. Jones whose election was effective on January 10, 2005, and Mr. Thrasher whose election will be effective on March 17, 2005.

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EXECUTIVE OFFICERS OF GULF POWER

(Identification of executive officers of Gulf Power is inserted in Part I in accordance with Regulation S-K, Item 401(b), Instruction 3.)
The ages of the officers set forth below are as of December 31, 2004.

Susan N. Story
President, Chief Executive Officer and Director
Age 44
Elected in 2003. President, Chief Executive Officer and Director since 2003. Previously served as Executive Vice President of Engineering and Construction Services at Southern Company Generation and Energy Marketing from 2001 to 2003; Vice President of Procurement and Materials at SCS from 2000 to 2001; and Vice President of Corporate Services and Corporate Real Estate at Alabama Power from 1997 to 2000.

Francis M. Fisher, Jr.
Vice President
Age 56
Elected in 1989. Vice President of Customer Operations since 1996.

P. Bernard Jacob
Vice President
Age 50
Elected in 2003. Vice President of External Affairs and Corporate Services since 2003. Previously served as Director of Information Resources Security and Program Management at SCS from 2002 to 2003; and Manager of Telecommunications Strategy at SCS from 1998 to 2002.

Ronnie R. Labrato
Vice President, Chief Financial Officer and Comptroller
Age 51
Elected in 2000. Vice President, Chief Financial Officer and Comptroller since July 27, 2001. Previously served as Comptroller and Chief Financial Officer from 2000 to 2001 and Comptroller from 1992 to 2000.

Penny M. Manuel
Vice President
Age 42
Elected in 2005. Vice President and Senior Production Officer since February 21, 2005. Previously served as Director, Human Resources, for Southern Company Generation from 2002 until February 2005; Vice President and Chief Information Officer, Alabama Power, and Regional Chief Information Officer for Southern Nuclear and SCS from 2001 until 2002; Manager, Business Technology Requirements, Southern Company Generation from 2000 to 2001; and Manager, Integrated Resource Planning, Alabama Power from 1999 to 2000.

      The officers of Gulf Power were elected for a term running from the last annual meeting of the directors (July 22, 2004) for one year until the next annual meeting or until their successors are elected and have qualified, except for Ms. Manuel whose election was effective as shown above.

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EXECUTIVE OFFICERS OF MISSISSIPPI POWER

(Identification of executive officers of Mississippi Power is inserted in Part I in accordance with Regulation S-K, Item 401(b), Instruction 3.) The ages of the officers set forth below are as of December 31, 2004.

Anthony J. Topazi
President, Chief Executive Officer and Director
Age 54
Elected in 2003. President, Chief Executive Officer and Director since January 1, 2004. Previously served as Executive Vice President of Southern Company Generation and Energy Marketing from November 2000 to December 2004; Senior Vice President of Southern Power from November 2002 to December 2004; Vice President of Southern Power from 2001 until November 2002 and Vice President of SCS — Fuel Services from 1999 to November 2000.

John W. Atherton
Vice President
Age 44
Elected in 2004. Vice President of External Affairs since January 2005. Previously served as the Director of Economic Development from September 2003 to January 2005; Manager, Sales and Marketing Services from April 2002 to August 2003; and Manager, State Legislative Affairs from August 1996 to April 2002.

Kimberly D. Flowers
Vice President
Age 40
Elected in 2005. Vice President and Senior Production Officer effective March 5, 2005. Previously served as Plant Manager, Plant Bowen, Georgia Power from November 2000 until March 2005.

Bobby J. Kerley
Vice President
Age 51
Elected in 2003. Vice President of Customer Services and Retail Marketing since December 2003. Previously served at Alabama Power as Division Vice President — Southeast Division Office from April 2001 to December 2003; Division Manager — Operations, Birmingham Division Office from January 2001 to April 2001; and Transmission Lines Manager, Corporate Headquarters from March 1997 to January 2001.

Michael W. Southern (1)
Vice President, Treasurer and
Chief Financial Officer
Age 52
Elected in 1995. Vice President, Treasurer and Chief Financial Officer since 2001. Previously served as Vice President, Secretary, Treasurer and Chief Financial Officer from 1995 to 2001.

Frances Turnage (2)
Comptroller
Age 56
Elected in 2005. Comptroller since 1993.

Gene L. Ussery, Jr. (3)
Vice President
Age 55
Elected in 2000. Vice President of Power Generation and Delivery since September 2000; Vice President of Power Generation at Gulf Power since May 2002. Previously served as Northern Cluster Manager at Georgia Power for Plants Hammond, Bowen and McDonough-Atkinson from July 2000 to September 2000; and Manager of Plant Bowen at Georgia Power from 1997 to 2000.

(1) Mr. Southern was elected Senior Vice President, Comptroller and Chief Financial Officer of Southern Power, effective March 17, 2005, and has resigned from Mississippi Power effective as of such date.

(2) Ms. Turnage was elected Vice President, Treasurer and Chief Financial Officer, effective March 17, 2005.

(3) Mr. Ussery was elected Vice President of Georgia Power effective February 16, 2005, and has resigned from Mississippi Power effective March 5, 2005.

      The officers of Mississippi Power were elected for a term running from the last annual meeting of the directors (April 28, 2004) for one year until the next annual meeting or until their successors are elected and have qualified, except for Mr. Atherton whose election was effective January 1, 2005, Ms. Flowers whose election will be effective as shown above and Ms. Turnage whose election will be effective March 17, 2005.

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PART II

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