Alabama Power (ALP-PQ) 10-Q 2006 Q1 Quarterly report

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
_________________________

FORM 10-Q

(X) QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2006

OR

( ) TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)
OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ___to___

Commission	Registrant, State of Incorporation,	I.R.S. Employer
File Number	Address and Telephone Number	Identification No.
1-3526	The Southern Company	58-0690070
	(A Delaware Corporation)
	30 Ivan Allen Jr. Boulevard, N.W.
	Atlanta, Georgia 30308
	(404) 506-5000
1-3164	Alabama Power Company	63-0004250
	(An Alabama Corporation)
	600 North 18th Street
	Birmingham, Alabama 35291
	(205) 257-1000
1-6468	Georgia Power Company	58-0257110
	(A Georgia Corporation)
	241 Ralph McGill Boulevard, N.E.
	Atlanta, Georgia 30308
	(404) 506-6526
0-2429	Gulf Power Company	59-0276810
	(A Florida Corporation)
	One Energy Place
	Pensacola, Florida 32520
	(850) 444-6111
001-11229	Mississippi Power Company	64-0205820
	(A Mississippi Corporation)
	2992 West Beach
	Gulfport, Mississippi 39501
	(228) 864-1211
1-5072	Savannah Electric and Power Company	58-0418070
	(A Georgia Corporation)
	600 East Bay Street
	Savannah, Georgia 31401
	(912) 644-7171
333-98553	Southern Power Company	58-2598670
	(A Delaware Corporation)
	30 Ivan Allen Jr. Boulevard, N.W.
	Atlanta, Georgia 30308
	(404) 506-5000

     Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or15(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 X  No___

     Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer” and “large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):

	Large
	Accelerated		Accelerated	Non-accelerated
Registrant	Filer		Filer	Filer
The Southern Company		X
Alabama Power Company					X
Georgia Power Company					X
Gulf Power Company					X
Mississippi Power Company					X
Savannah Electric and Power Company					X
Southern Power Company					X

   Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act.) Yes___  NoX(Response applicable to all registrants.)

	Description of	Shares Outstanding
Registrant	Common Stock	at March 31, 2006
The Southern Company	Par Value $5 Per Share		742,048,440
Alabama Power Company	Par Value $40 Per Share		9,250,000
Georgia Power Company	Without Par Value		7,761,500
Gulf Power Company	Without Par Value		992,717
Mississippi Power Company	Without Par Value		1,121,000
Savannah Electric and Power Company	Par Value $5 Per Share		10,844,635
Southern Power Company	Par Value $0.01 Per Share		1,000

     This combined Form 10-Q 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.

2

INDEX TO QUARTERLY REPORT ON FORM 10-Q
March 31, 2006

	Page
	Number
DEFINITIONS		5
CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION		6
PART I — FINANCIAL INFORMATION
Item 1. Financial Statements (Unaudited)
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The Southern Company and Subsidiary Companies
Condensed Consolidated Statements of Income		8
Condensed Consolidated Statements of Cash Flows		9
Condensed Consolidated Balance Sheets		10
Condensed Consolidated Statements of Comprehensive Income		12
Management’s Discussion and Analysis of Financial Condition and Results of Operations		13
Alabama Power Company
Condensed Statements of Income		29
Condensed Statements of Comprehensive Income		29
Condensed Statements of Cash Flows		30
Condensed Balance Sheets		31
Management’s Discussion and Analysis of Financial Condition and Results of Operations		33
Georgia Power Company
Condensed Statements of Income		44
Condensed Statements of Comprehensive Income		44
Condensed Statements of Cash Flows		45
Condensed Balance Sheets		46
Management’s Discussion and Analysis of Financial Condition and Results of Operations		48
Gulf Power Company
Condensed Statements of Income		59
Condensed Statements of Comprehensive Income		59
Condensed Statements of Cash Flows		60
Condensed Balance Sheets		61
Management’s Discussion and Analysis of Financial Condition and Results of Operations		63
Mississippi Power Company
Condensed Statements of Income		72
Condensed Statements of Comprehensive Income		72
Condensed Statements of Cash Flows		73
Condensed Balance Sheets		74
Management’s Discussion and Analysis of Financial Condition and Results of Operations		76
Savannah Electric and Power Company
Condensed Statements of Income		86
Condensed Statements of Comprehensive Income		86
Condensed Statements of Cash Flows		87
Condensed Balance Sheets		88
Management’s Discussion and Analysis of Financial Condition and Results of Operations		90
Southern Power Company
Condensed Consolidated Statements of Income		101
Condensed Consolidated Statements of Comprehensive Income		101
Condensed Consolidated Statements of Cash Flows		102
Condensed Consolidated Balance Sheets		103
Management’s Discussion and Analysis of Financial Condition and Results of Operations		105
Notes to the Condensed Financial Statements		112
Item 3. Quantitative and Qualitative Disclosures about Market Risk		27
Item 4. Controls and Procedures		27

3

INDEX TO QUARTERLY REPORT ON FORM 10-Q
March 31, 2006

	Page
	Number
PART II — OTHER INFORMATION
Item 1. Legal Proceedings		125
Item 1A. Risk Factors		125
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds		125
Item 3. Defaults Upon Senior Securities	Inapplicable
Item 4. Submission of Matters to a Vote of Security Holders	Inapplicable
Item 5. Other Information	Inapplicable
Item 6. Exhibits		126
Signatures		131

4

DEFINITIONS

TERM	MEANING
Alabama Power	Alabama Power Company
AFUDC	Allowance for funds used during construction
BMA	Bond Market Association
Clean Air Act	Clean Air Act Amendments of 1990
DOE	U.S. Department of Energy
ECO Plan	Environmental Compliance Overview Plan
EPA	U.S. Environmental Protection Agency
ERISA	Employee Retirement Income Security Act of 1974, as amended
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
Form 10-K	Combined Annual Report on Form 10-K of Southern Company, Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, and Southern Power for the year ended December 31, 2005 and, with respect to Southern Company, Amendment No. 1 and Amendment No. 2 thereto
Georgia Power	Georgia Power Company
Gulf Power	Gulf Power Company
IIC	Intercompany Interchange Contract
IRC	Internal Revenue Code of 1986, as amended
IRS	Internal Revenue Service
KWH	Kilowatt-hour
LIBOR	London Interbank Offered Rate
Mirant	Mirant Corporation
Mississippi Power	Mississippi Power Company
Moody’s	Moody’s Investors Service, Inc
MW	Megawatt
NRC	Nuclear Regulatory Commission
NSR	New Source Review
PEP	Performance Evaluation Plan
PPA	Power Purchase Agreement
PSC	Public Service Commission
retail operating companies	Alabama Power, Georgia Power, Gulf Power, Mississippi Power, and Savannah Electric
S&P	Standard and Poor’s, a division of The McGraw-Hill Companies, Inc.
Savannah Electric	Savannah Electric and Power Company
SCS	Southern Company Services, Inc.
SEC	Securities and Exchange Commission
Southern Company	The Southern Company
Southern Company system	Southern Company, the retail operating companies, Southern Power, and other subsidiaries
Southern Power	Southern Power Company
Super Southeast	Southern Company’s traditional service territory, Alabama, Florida, Georgia, and Mississippi, plus the surrounding states of Kentucky, Louisiana, North Carolina, South Carolina, Tennessee, and Virginia

5

CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

     This Quarterly Report on Form 10-Q contains forward-looking statements. Forward-looking statements include, among other things, statements concerning the strategic goals for the wholesale business, storm damage cost recovery and repairs, environmental regulations and expenditures, the proposed merger of Savannah Electric and Georgia Power, financing activities, completion of construction projects, impacts of adoption of new accounting rules, access to sources of capital, 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:

• the impact of recent and future federal and state regulatory change, including legislative and regulatory initiatives regarding deregulation and restructuring of the electric utility industry, implementation of the Energy Policy Act of 2005, and also changes in environmental, tax, and other laws and regulations to which Southern Company and its subsidiaries are subject, as well as changes in application of existing laws and regulations;

• current and future litigation, regulatory investigations, proceedings, or inquiries, including the pending EPA civil actions against certain Southern Company subsidiaries, FERC matters, IRS audits, and Mirant matters;

• the effects, extent, and timing of the entry of additional competition in the markets in which Southern Company’s subsidiaries operate;

• variations in demand for electricity and gas, including those relating to weather, the general economy and population, and business growth (and declines);

• available sources and costs of fuels;

• ability to control costs;

• investment performance of Southern Company’s employee benefit plans;

• advances in technology;

• state and federal rate regulations and the impact of pending and future rate cases and negotiations, including rate cases relating to fuel cost recovery;

• the performance of projects undertaken by the non-utility businesses and the success of efforts to invest in and develop new opportunities;

• internal restructuring or other restructuring options that may be pursued;

• potential business strategies, including acquisitions or dispositions of assets or businesses, which cannot be assured to be completed or beneficial to Southern Company or its subsidiaries;

• the ability of counterparties of Southern Company and its subsidiaries to make payments as and when due;

• the ability to obtain new short- and long-term contracts with neighboring utilities;

• the direct or indirect effect on Southern Company’s business resulting from terrorist incidents and the threat of terrorist incidents;

• interest rate fluctuations and financial market conditions and the results of financing efforts, including Southern Company’s and its subsidiaries’ credit ratings;

• the ability of Southern Company and its subsidiaries to obtain additional generating capacity at competitive prices;

• catastrophic events such as fires, earthquakes, explosions, floods, hurricanes, or other similar occurrences;

• the direct or indirect effects on Southern Company’s business resulting from incidents similar to the August 2003 power outage in the Northeast;

• the effect of accounting pronouncements issued periodically by standard setting bodies; and

• other factors discussed elsewhere herein and in other reports filed by the registrants from time to time with the SEC.

Each registrant expressly disclaims any obligation to update any forward-looking statements.

6

THE SOUTHERN COMPANY
AND SUBSIDIARY COMPANIES

7

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Revenues:
Retail revenues	$	2,471,413		$	2,268,809
Sales for resale		414,869			347,125
Other electric revenues		110,990			101,095
Other revenues		65,988			70,001
Total operating revenues		3,063,260			2,787,030
Operating Expenses:
Fuel		1,048,545			864,621
Purchased power		104,411			98,216
Other operations		562,452			516,428
Maintenance		283,630			294,092
Depreciation and amortization		298,926			291,110
Taxes other than income taxes		175,003			162,884
Total operating expenses		2,472,967			2,227,351
Operating Income		590,293			559,679
Other Income and (Expense):
Allowance for equity funds used during construction		11,527			16,859
Interest income		6,672			5,272
Equity in losses of unconsolidated subsidiaries		(32,575	)		(23,104	)
Leveraged lease income		18,103			18,248
Interest expense, net of amounts capitalized		(176,375	)		(138,987	)
Interest expense to affiliate trusts		(30,629	)		(31,930	)
Preferred and preference dividends of subsidiaries		(9,015	)		(7,402	)
Other income (expense), net		(10,865	)		(5,207	)
Total other income and (expense)		(223,157	)		(166,251	)
Earnings From Continuing Operations Before Income Taxes		367,136			393,428
Income taxes		107,022			75,887
Earnings From Continuing Operations		260,114			317,541
Earnings from discontinued operations, net of income taxes of $942 and $3,435 for 2006 and 2005, respectively		1,493			5,419
Consolidated Net Income	$	261,607		$	322,960
Common Stock Data:
Earnings per share from continuing operations-
Basic	$	0.35		$	0.43
Diluted	$	0.35		$	0.42
Earnings per share including discontinued operations-
Basic	$	0.35		$	0.43
Diluted	$	0.35		$	0.43
Average number of basic shares of common stock outstanding (in thousands)		742,195			744,025
Average number of diluted shares of common stock outstanding (in thousands)		747,039			748,672
Cash dividends paid per share of common stock	$	0.3725		$	0.3575

The accompanying notes as they relate to Southern Company are an integral part of these condensed financial statements.

8

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Activities:
Consolidated net income	$	261,607		$	322,960
Adjustments to reconcile consolidated net income to net cash provided from operating activities —
Depreciation and amortization		351,946			343,071
Deferred income taxes and investment tax credits		(39,650	)		111,385
Allowance for equity funds used during construction		(11,527	)		(16,859	)
Equity in losses of unconsolidated subsidiaries		32,575			23,104
Leveraged lease income		(18,103	)		(18,248	)
Pension, postretirement, and other employee benefits		18,448			13,793
Stock option expense		19,104			—
Tax benefit of stock options		826			15,049
Hedge settlements		18,006			(18,357	)
Storm damage accounting order		—			45,000
Other, net		(3,434	)		(16,106	)
Changes in certain current assets and liabilities —
Receivables		236,127			(16,952	)
Fossil fuel stock		(78,471	)		(35,716	)
Materials and supplies		(11,089	)		(5,120	)
Other current assets		(41,642	)		5,260
Accounts payable		(310,962	)		(88,579	)
Accrued taxes		(9,425	)		(231,334	)
Accrued compensation		(337,600	)		(275,701	)
Other current liabilities		(18,331	)		14,458
Net cash provided from operating activities		58,405			171,108
Investing Activities:
Property additions		(546,261	)		(458,842	)
Nuclear decommissioning trust fund purchases		(172,551	)		(176,854	)
Nuclear decommissioning trust fund sales		165,671			168,155
Proceeds from property sales		150,521			9,463
Investment in unconsolidated subsidiaries		(37,748	)		(23,913	)
Cost of removal net of salvage		(31,230	)		(16,040	)
Other		(33,312	)		(48,729	)
Net cash used for investing activities		(504,910	)		(546,760	)
Financing Activities:
Increase in notes payable, net		433,101			363,710
Proceeds —
Long-term debt		800,000			500,000
Common stock		13,875			56,031
Gross excess tax benefit of stock options		1,960			—
Redemptions —
Long-term debt		(322,839	)		(252,421	)
Long-term debt to affiliate trusts		(67,457	)		—
Preferred and preference stock		(14,569	)		—
Common stock repurchased		(117	)		—
Payment of common stock dividends		(276,442	)		(265,958	)
Other		(22,332	)		(12,370	)
Net cash provided from financing activities		545,180			388,992
Net Change in Cash and Cash Equivalents		98,675			13,340
Cash and Cash Equivalents at Beginning of Period		202,111			368,449
Cash and Cash Equivalents at End of Period	$	300,786		$	381,789
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $4,942 and $6,708 capitalized for 2006 and 2005, respectively)	$	198,762		$	170,760
Income taxes (net of refunds)	$	919		$	31,855

The accompanying notes as they relate to Southern Company are an integral part of these condensed financial statements.

9

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Assets	2006			2005
	(in thousands)
Current Assets:
Cash and cash equivalents	$	300,786		$	202,111
Receivables —
Customer accounts receivable		800,744			868,665
Unbilled revenues		268,100			303,782
Under recovered regulatory clause revenues		783,010			754,522
Other accounts and notes receivable		308,463			409,685
Accumulated provision for uncollectible accounts		(35,515	)		(37,510	)
Fossil fuel stock, at average cost		493,709			402,579
Vacation pay		117,073			116,699
Materials and supplies, at average cost		664,225			665,754
Assets from risk management activities		78,956			124,607
Prepaid expenses		191,986			131,324
Other		240,479			262,659
Total current assets		4,212,016			4,204,877
Property, Plant, and Equipment:
In service		43,956,095			43,578,501
Less accumulated depreciation		15,987,807			15,727,300
		27,968,288			27,851,201
Nuclear fuel, at amortized cost		269,916			261,997
Construction work in progress		1,403,760			1,367,255
Total property, plant, and equipment		29,641,964			29,480,453
Other Property and Investments:
Nuclear decommissioning trusts, at fair value		995,776			953,554
Leveraged leases		1,088,984			1,082,100
Other		324,213			337,236
Total other property and investments		2,408,973			2,372,890
Deferred Charges and Other Assets:
Deferred charges related to income taxes		931,078			936,729
Prepaid pension costs		1,023,360			1,021,797
Unamortized debt issuance expense		172,019			161,583
Unamortized loss on reacquired debt		303,909			309,409
Deferred under recovered regulatory clause revenues		438,740			530,668
Other regulatory assets		518,232			519,005
Other		327,113			339,294
Total deferred charges and other assets		3,714,451			3,818,485
Total Assets	$	39,977,404		$	39,876,705

The accompanying notes as they relate to Southern Company are an integral part of these condensed financial statements.

10

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES
CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Liabilities and Stockholders' Equity	2006			2005
	(in thousands)
Current Liabilities:
Securities due within one year	$	893,632		$	900,699
Notes payable		1,690,530			1,257,428
Accounts payable		845,142			1,229,253
Customer deposits		230,485			219,781
Accrued taxes —
Income taxes		224,070			103,925
Other		185,124			318,978
Accrued interest		195,558			204,292
Accrued vacation pay		143,007			143,816
Accrued compensation		121,125			458,573
Other		409,433			403,606
Total current liabilities		4,938,106			5,240,351
Long-term Debt		11,340,843			10,957,903
Long-term Debt Payable to Affiliated Trusts		1,893,187			1,888,469
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes		5,712,443			5,735,502
Deferred credits related to income taxes		305,960			311,083
Accumulated deferred investment tax credits		521,148			527,172
Employee benefit obligations		955,677			929,908
Asset retirement obligations		1,132,367			1,117,280
Other cost of removal obligations		1,278,907			1,295,215
Other regulatory liabilities		307,013			323,180
Other		272,412			265,838
Total deferred credits and other liabilities		10,485,927			10,505,178
Total Liabilities		28,658,063			28,591,901
Preferred and Preference Stock of Subsidiaries		595,616			595,626
Common Stockholders’ Equity:
Common stock, par value $5 per share —
Authorized — 1 billion shares
Issued — March 31, 2006: 751,859,492 Shares; — December 31, 2005: 751,810,927 Shares
Treasury — March 31, 2006: 9,811,052 Shares; — December 31, 2005: 10,362,970 Shares
Par value		3,759,297			3,759,055
Paid-in capital		1,101,043			1,084,799
Treasury, at cost		(340,309	)		(358,892	)
Retained earnings		6,317,298			6,332,023
Accumulated other comprehensive loss		(113,604	)		(127,807	)
Total Common Stockholders’ Equity		10,723,725			10,689,178
Total Liabilities and Stockholders’ Equity	$	39,977,404		$	39,876,705

The accompanying notes as they relate to Southern Company are an integral part of these condensed financial statements.

11

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006		2005
	(in thousands)
Consolidated Net Income	$	261,607	$	322,960
Other comprehensive income (loss) — continuing operations:
Change in fair value of marketable securities, net of tax of $1,609 and $(1,729), respectively		2,521		(3,326	)
Changes in fair value of qualifying hedges, net of tax of $7,130 and $935, respectively		11,392		1,435
Reclassification adjustment for amounts included in net income, net of tax of $241 and $1,318, respectively		290		2,054
Total other comprehensive income — continuing operations		14,203		163
Other comprehensive income — discontinued operations:
Changes in fair value of qualifying hedges, net of tax of $1,090		—		1,728
Reclassification adjustment for amounts included in net income, net of tax of $692		—		1,097
Total other comprehensive income — discontinued operations		—		2,825
COMPREHENSIVE INCOME	$	275,810	$	325,948

The accompanying notes as they relate to Southern Company are an integral part of these condensed financial statements.

12

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2006 vs. FIRST QUARTER 2005

OVERVIEW

Discussion of the results of operations is focused on Southern Company’s primary business of electricity sales in the Southeast by the retail operating companies — Alabama Power, Georgia Power, Gulf Power, Mississippi Power, and Savannah Electric — and Southern Power. Southern Power is an electric wholesale generation subsidiary with market-based rate authority. Southern Company’s other business activities include investments in synthetic fuels and leveraged lease projects, telecommunications, and energy-related services. For additional information on these businesses, see BUSINESS — The SOUTHERN System — “Retail Operating Companies,” “Southern Power,” and “Other Business” in Item 1 of the Form 10-K.

     Hurricanes Dennis and Katrina hit Southern Company’s service territory in July and August 2005, respectively. As a result of these storms, as well as Hurricane Ivan in September 2004, Southern Company has incurred significant restoration costs. In addition, fuel costs at each of the retail operating companies rose significantly during 2005 and the first quarter of 2006. Southern Company continues to work with its regulators to develop methods to enable the timely recovery of these costs. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Storm Damage Cost Recovery” of Southern Company in Item 7 of the Form 10-K for additional information.

     Southern Company continues to focus on several key performance indicators. These indicators include customer satisfaction, plant availability, system reliability, and earnings per share. For additional information on these indicators, see MANAGEMENT’S DISCUSSION AND ANALYSIS — OVERVIEW — “Key Performance Indicators” of Southern Company in Item 7 of the Form 10-K.

RESULTS OF OPERATIONS

Earnings

Southern Company’s first quarter earnings were $261.6 million ($0.35 per share) compared with $323.0 million ($0.43 per share) for the corresponding period in 2005. The decrease in earnings in the first quarter 2006 resulted primarily from higher other operations and maintenance expenses (excluding effects of a 2005 Alabama PSC accounting order), higher interest expense, reduction in tax credits related to synfuel investments, and milder weather compared to the first quarter of 2005. These decreases to earnings were partially offset by an increase in revenues resulting from sustained economic strength and customer growth in the Southern Company service area.

     Significant income statement items appropriate for discussion include the following:

	Increase (Decrease)
	First Quarter
	(in thousands)			%
Retail revenues	$	202,604			8.9
Sales for resale		67,744			19.5
Other electric revenues		9,895			9.8
Fuel expense		183,924			21.3
Purchased power expense		6,195			6.3
Other operations expense		46,024			8.9
Maintenance expense		(10,462	)		(3.6	)
Taxes other than income taxes		12,119			7.4
Allowance for equity funds used during construction		(5,332	)		(31.6	)
Equity in losses of unconsolidated subsidiaries		9,471			41.0
Interest expense, net of amounts capitalized		37,388			26.9
Other income (expense), net		(5,658	)		(108.7	)
Income taxes		31,135			41.0

13

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Retail revenues.The chart below reflects the primary drivers of the 8.9% increase in retail revenues in the first quarter of 2006 when compared to the same period in 2005. Changes in revenue related to certain cost recovery mechanisms such as fuel and storm damage have no effect on net income. In the first quarter 2006, retail KWH sales increased by 0.3% from the same period in 2005, primarily due to continued customer and demand growth from sustained economic strength in the Southeast. The number of retail customers increased by 1.3% and weather-adjusted average consumption by retail customers increased by 0.6% for the first quarter of 2006 when compared with the first quarter 2005.

     Details of retail revenues are as follows:

	First Quarter
	(in millions)			% change
Retail — prior year	$	2,269
Change in —
Base rates		14			0.6
Sales growth		28			1.2
Weather		(6	)		(0.3	)
Fuel cost recovery		146			6.5
Other cost recovery		20			0.9
Retail — current year	$	2,471			8.9	%

     Sales for resale. In the first quarter 2006, sales for resale increased $67.7 million, or 19.5%, over the same period in 2005. The increase reflects higher fuel revenues of $27 million due to a 20.6% increase in the cost of fuel per net KWH generated and a $65 million increase in revenues associated with sales under long-term contracts, offset by a $24 million decrease in excess capacity revenues.

     Other electric revenues.In the first quarter 2006, when compared to the same period in 2005, other electric revenues increased $9.9 million, or 9.8%. The increase was primarily due to higher transmission revenues of $4.1 million, increased cogeneration revenues of $4.3 million, and higher outdoor lighting revenues of $1.4 million.

     Fuel and purchased power expense. Fuel and purchased power expense increased $190.1 million in the first quarter 2006 when compared to the same period in 2005 due to a $201.6 million increase in the cost of fuel offset by a $11.5 million decrease related to fewer total KWHs generated and purchased. Increases in fuel expense at the retail operating companies are generally offset by fuel revenues and do not affect net income. See FUTURE EARNINGS POTENTIAL — “FERC and State PSC Matters — Retail Fuel Cost Recovery” herein for additional information. Fuel expenses incurred under Southern Power’s PPAs are generally the responsibility of the counterparties and do not significantly affect net income.

     Other operations expense.The $46.0 million increase in other operations expense in the first quarter 2006 as compared with the same period in the prior year is due to a $21.5 million increase in administrative and general expense, primarily additional compensation related to expensing of stock options, and a $8.3 million increase in customer accounts, service and sales expense, primarily technology costs, promotional expenses for energy efficiency programs, and an increase in uncollectible accounts. The increase was also attributable to a $9.4 million increase in production expense and a $6.8 million increase in transmission and distribution expense. Production, transmission, and distribution expenses fluctuate from year to year due to timing of plant outages and system maintenance projects as well as normal increases in costs.

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FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Maintenance expense.The $10.5 million decrease in maintenance expense in the first quarter 2006 compared with the same period in 2005 is mainly attributable to $45 million of expenses recorded in the first quarter of 2005 by Alabama Power in accordance with an accounting order approved by the Alabama PSC to offset the costs of Hurricane Ivan and restore the natural disaster reserve. In accordance with the accounting order, Alabama Power also returned certain regulatory liabilities related to deferred taxes to its retail customers; therefore, the combined effects of this accounting order had no impact on net income. See Note 3 to the financial statements of Southern Company under “Storm Damage Cost Recovery” in Item 8 of the Form 10-K and “Income taxes” below for additional information. Excluding the impact of the $45 million Alabama Power accounting order, maintenance expense increased $34.5 million in the first quarter of 2006 over 2005 due to an
$18.4 million increase in production maintenance expense and a $15.3 million increase in transmission and distribution maintenance expense. Production, transmission, and distribution expenses fluctuate from year to year due to timing of plant outages and system maintenance projects as well as normal increases in costs.

     Taxes other than income taxes.The $12.1 million increase in taxes other than income taxes in the first quarter 2006 compared with the same period in 2005 is primarily a result of increases in municipal franchise and gross receipts taxes associated with increases in revenues from energy sales and an increase in property taxes associated with changes in property tax rates, changes in the assessed value of properties, and increases in property value associated with the additions of Plants McIntosh and Oleander.

     Allowance for equity funds used during construction. The $5.3 million decrease in AFUDC equity for the first quarter 2006 compared to the same period in the prior year relates to the completion of the Plant McIntosh combined cycle units 10 and 11 by Georgia Power and Savannah Electric in June 2005. AFUDC equity is non-taxable.

     Equity in losses of unconsolidated subsidiaries.The $9.5 million increase in equity in losses of unconsolidated subsidiaries in the first quarter 2006 compared with the same period in the prior year reflects $12.1 million in increased production at synfuel production facilities that generate operating losses. These partnerships also claim federal income tax credits that offset these operating losses and make the projects profitable. The increase was offset by $2.6 million in expense recovery associated with the reserve recorded in the first quarter 2006 related to a projected phase-out of 2006 tax credits resulting from increases in current and projected future oil prices. See FUTURE EARNINGS POTENTIAL — “Income Tax Matters — Synthetic Fuel Tax Credits” herein for further information.

     Interest expense, net of amounts capitalized.Interest charges and other financing costs increased by $37.4 million in the first quarter of 2006 when compared to the same period in 2005 associated with a $901.4 million increase in notes payable and a $525.4 million increase in long-term debt outstanding at March 31, 2006 compared to March 31, 2005 as well as an increase in average interest rates on variable rate debt. Variable rates on pollution control bonds are highly correlated with the BMA Municipal Swap Index, which averaged 3.1% in the first quarter of 2006 compared to 1.9% in the first quarter of 2005. Variable rates on commercial paper and senior notes are highly correlated with the one-month LIBOR, which averaged 4.6% in the first quarter of 2006 and 2.6% in the first quarter of 2005. The increase in interest expense was also the result of $5.0 million related to early redemption of trust preferred securities. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Financing Activities” of Southern Company in Item 7 of the Form 10-K and herein for additional information.

     Other income (expense), net.The $5.7 million decrease in other income (expense), net, in the first quarter of 2006 compared to the same period in 2005 is primarily due to Alabama Power’s $5.0 million settlement with the EPA in the NSR litigation. See Note 3 to the financial statements of Southern Company under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under “NEW SOURCE REVIEW ACTIONS — New Source Review Litigation” for further information.

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     Income taxes.The $31.1 million increase in income taxes in the first quarter 2006 when compared to the same period in the prior year is primarily due to the impact of the Alabama PSC accounting order recorded in the first quarter 2005, discussed under “Maintenance expense” above, and $19.5 million associated with the synthetic fuel reserve discussed under “Equity in losses of unconsolidated subsidiaries” above. The net after-tax effect of the synthetic fuel reserve is $16.9 million. See FUTURE EARNINGS POTENTIAL — “Income Tax Matters — Synthetic Fuel Tax Credits” herein for further information. These increases were partially offset by a decrease in income taxes associated with lower taxable income in the first quarter of 2006 as compared to the same period in 2005.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Southern Company’s future earnings potential. The level of future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Southern Company’s primary business of selling electricity. These factors include the retail operating companies’ ability to maintain a stable regulatory environment that continues to allow for the recovery of all prudently incurred costs. Another major factor is the profitability of the competitive market-based wholesale generating business and federal regulatory policy, which may impact Southern Company’s level of participation in this market. Future earnings for the electricity business in the near term will depend, in part, upon the availability of tax credits on synfuel investments and growth in energy sales, which is subject to a number of factors. These factors include weather, competition, new energy contracts with neighboring utilities, energy conservation practiced by customers, the price of electricity, the price elasticity of demand, and the rate of economic growth in the service area. For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL of Southern Company in Item 7 of the Form 10-K.

Environmental Matters

Compliance costs related to the Clean Air Act and other environmental regulations could affect earnings if such costs cannot be fully recovered in rates on a timely basis. For additional information, including information on certain environmental litigation, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters” of Southern Company in Item 7 and Note 3 to the financial statements of Southern Company under “Environmental Matters” in Item 8 of the Form 10-K.

New Source Review Litigation

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Actions” of Southern Company in Item 7 and Note 3 to the financial statements of Southern Company under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K for additional information regarding a civil action brought by the EPA alleging that Alabama Power had violated the NSR provisions of the Clean Air Act and related state laws with respect to certain of its coal-fired generating facilities. On April 24, 2006, as a result of court-ordered mediation, the EPA filed, with the U.S. District Court for the Northern District of Alabama, statements designed to result in a judgment being entered in favor of Alabama Power on the claims related to Plants Barry, Gaston, Gorgas, and Greene County. In turn, Alabama Power agreed to the filing with the district court of a proposed consent decree that, upon such court’s approval, would require Alabama Power to pay $100,000 to resolve the EPA’s claim for a civil penalty related to alleged violations at Plant Miller. The proposed consent decree also formalizes specific emissions reductions to be accomplished by Alabama Power. These reductions are consistent with other Clean Air Act programs that require emissions reductions. Alabama Power further agreed to donate $4.9 million of sulfur dioxide emission allowances to a nonprofit charitable organization. As a result, Alabama Power recognized $5 million in other income (expense), net related to the proposed consent decree. The final

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resolution of these claims is dependent on further court action and subject to possible appeals, and therefore, cannot be determined at this time.

New Source Review Reform Rules

On October 20, 2005, the EPA published a proposed rule clarifying the test for determining when an emissions increase is subject to the NSR requirements. On March 17, 2006, the U.S. Court of Appeals for the District of Columbia Circuit vacated the EPA’s proposed rule which sought to clarify the scope of the existing Routine Maintenance, Repair, and Replacement Exclusion. Because this rule was not yet in effect, the court’s ruling is not anticipated to have any impact on Southern Company. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Actions” of Southern Company in Item 7 and Note 3 to the financial statements of Southern Company under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K for additional information.

Plant Wansley Environmental Litigation

On March 30, 2006, the U.S. Court of Appeals for the Eleventh Circuit ruled in favor of Georgia Power on its appeal and reversed the district court’s order regarding certain alleged opacity violations at Plant Wansley. The court of appeals remanded the case to the U.S. District Court for the Northern District of Georgia for further proceedings consistent with its decision. The ultimate outcome of this matter cannot now be determined. See MANAGEMENT’S DISCUSSION AND ANALYSIS - - FUTURE EARNINGS POTENTIAL — “Environmental Matters — Plant Wansley Environmental Litigation” of Southern Company in Item 7 and Note 3 to the financial statements of Southern Company under “Environmental Matters — Plant Wansley Environmental Litigation” in Item 8 of the Form 10-K for additional information.

FERC and State PSC Matters

Market-Based Rate Authority

See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Market-Based Rate Authority” of Southern Company in Item 7 and Note 3 to the financial statements of Southern Company under “FERC Matters — Market-Based Rate Authority” in Item 8 of the Form 10-K for information on the FERC’s April 2004 order adopting a new interim analysis for measuring generation market power and a proceeding initiated by the FERC in December 2004 to assess Southern Company’s generation dominance within its retail service territory. Each of the retail operating companies and Southern Power has authorization from the FERC to sell power to non-affiliates 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. On February 15, 2005, Southern Company submitted additional information related to generation dominance in Southern Company’s retail service territory. A hearing before an administrative law judge scheduled for March 2006 has been held in abeyance to allow the parties to explore settlement. Any new market-based rate transactions in its 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. The impact of all such sales through March 31, 2006 is not expected to exceed $19 million for the Southern Company system. The refund period covers 15 months. In the event that the FERC’s default mitigation measures for entities that are found to have market power are ultimately applied, the retail operating companies and Southern Power 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 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.

     In addition, in May 2005, the FERC initiated an investigation to determine whether Southern Company satisfies the other three parts of the FERC’s market-based rate analysis: transmission market power, barriers to

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entry, and affiliate abuse or reciprocal dealing. The FERC established a new 15-month refund period related to this expanded investigation. Any new market-based rate transactions involving any Southern Company subsidiary will be subject to refund to the extent the FERC orders lower rates as a result of this new investigation, with the refund period beginning July 19, 2005. The impact of all such sales through March 31, 2006 is not expected to exceed $37 million, of which $15 million relates to sales inside the retail service territory discussed above. The FERC also directed that this expanded proceeding be held in abeyance pending the outcome of the proceeding on the IIC discussed below.

     Southern Company and its subsidiaries believe that there is no meritorious basis for this proceeding and are vigorously defending themselves in this matter. However, the final outcome of this matter, including any remedies to be applied in the event of an adverse ruling in this proceeding, cannot now be determined.

Intercompany Interchange Contract

Also in May 2005, the FERC initiated a new proceeding to examine (1) the provisions of the IIC among Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, Southern Power, and SCS, as agent, under the terms of which the power pool of Southern Company is operated, and, in particular, the propriety of the continued inclusion of Southern Power as a party to the IIC, (2) whether any parties to the IIC have violated the FERC’s standards of conduct applicable to utility companies that are transmission providers, and (3) whether Southern Company’s code of conduct defining Southern Power as a “system company” rather than a “marketing affiliate” is just and reasonable. In connection with the formation of Southern Power, the FERC authorized Southern Power’s inclusion in the IIC in 2000. The FERC also previously approved Southern Company’s code of conduct. The FERC order directs that the administrative law judge who presided over a proceeding involving approval of PPAs between Southern Power and Georgia Power and Savannah Electric be assigned to preside over the hearing in this proceeding and that the testimony and exhibits presented in that proceeding be preserved to the extent appropriate. Effective July 19, 2005, revenues from transactions under the IIC involving any Southern Company subsidiaries will be subject to refund to the extent the FERC orders any changes to the IIC. On April 11, 2006, Southern Company, Calpine Corporation, Coral Energy, and Dalton Utilities filed a settlement offer that would resolve the proceeding. The offer is pending before the FERC and does not require any refunds. However, because the offer is pending, the final outcome of this matter cannot now be determined.See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Intercompany Interchange Contract” of Southern Company in Item 7 and Note 3 to the financial statements of Southern Company under “FERC Matters — Intercompany Interchange Contract” in Item 8 of the Form 10-K for additional information.

Retail Fuel Cost Recovery

The retail operating companies each have established fuel cost recovery rates approved by their respective state PSCs. In 2005 and the first quarter of 2006, the retail operating companies have experienced higher than expected fuel costs for coal and gas. These higher fuel costs have increased the under recovered fuel costs included in the balance sheets to approximately $1.2 billion at March 31, 2006. Operating revenues are adjusted for differences in actual recoverable fuel costs and amounts billed in current regulated rates. Accordingly, changes to the billing factors will have no significant effect on Southern Company’s revenues or net income, but will affect cash flow. The retail operating companies will continue to monitor the under recovered fuel cost balance in light of these higher fuel costs. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Fuel Cost Recovery” of Southern Company in Item 7 and Note 3 to the financial statements of Southern Company under “Alabama Power Retail Regulatory Matters” and “Georgia Power Retail Regulatory Matters” in Item 8 of the Form 10-K for additional information.

     On March 17, 2006, Georgia Power and Savannah Electric filed a combined request for fuel cost recovery rate changes with the Georgia PSC to be effective July 1, 2006. The requested changes will allow for the

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recovery of fuel costs based on an estimate of future fuel costs, as well as the collection of the existing under recovered fuel expenses. The filing also includes proposed fuel rate changes related to the previously announced proposed merger of the two companies, which is expected to be completed by July 2006.

     The request would result in an increase of about $7.22 per month, or about 8.1%, on the average Georgia Power residential customer bill and a decrease of about $8.14 a month, or about 6.4%, on the average residential bill for a customer in the former Savannah Electric territory. The impact for business customers would depend upon the customer’s specific rate class and usage.

     The request would increase Georgia Power’s revenues by $556 million a year, of which approximately $106 million relates to collection of the existing under recovered fuel costs. As of the end of March 2006, Savannah Electric had an under recovered fuel balance of $81 million, and Georgia Power had an under recovered fuel balance of about $784 million, including approximately $392 million related to fuel used since June 2005. The proposed fuel rates are based on an amortization period of 35 months for Georgia Power customers and 41 months for former Savannah Electric territory customers. Hearings are scheduled for May 2006 and the Georgia PSC is expected to rule on this matter in June 2006. The outcome of this matter cannot be determined at this time.

Storm Damage Cost Recovery

In July and August 2005, Hurricanes Dennis and Katrina, respectively, hit the Gulf Coast of the United States and caused significant damage within Southern Company’s service area, including portions of Gulf Power, Alabama Power, and Mississippi Power. Hurricane Ivan hit the Gulf coast of Florida and Alabama in September 2004, causing significant damage to the service areas of both Gulf Power and Alabama Power. Each retail operating company maintains a reserve to cover the cost of damages from major storms to its transmission and distribution lines and the cost of uninsured damages to its generation facilities and other property. In addition, each of the affected retail operating companies has been authorized by its state PSC to defer the portion of the hurricane restoration costs that exceeded the balance in its storm damage reserve account. As of March 31, 2006, the deficit balance in Southern Company’s storm damage reserve accounts totaled approximately $375 million, of which approximately $70 million and $305 million, respectively, are included in the Condensed Balance Sheets herein under “Other Current Assets” and “Other Regulatory Assets.” See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Storm Damage Cost Recovery” of Southern Company in Item 7 and Note 3 to the financial statements of Southern Company under “Storm Damage Cost Recovery” in Item 8 of the Form 10-K for additional information.

     In October 2005, the Mississippi PSC issued an Interim Accounting Order requiring Mississippi Power to recognize a regulatory asset in an amount equal to the retail portion of the recorded Hurricane Katrina restoration costs, including both operation and maintenance expenditures and capital additions. In December 2005, Mississippi Power filed with the Mississippi PSC a detailed review of all Hurricane Katrina restoration costs as required in the Interim Accounting Order. Mississippi Power is currently working with the Mississippi PSC to establish a method to recover all such prudently incurred costs, while minimizing the impact on Mississippi Power’s customers. The Department of Defense emergency supplemental appropriations bill, enacted in December 2005 to address restoration efforts related to hurricanes in the Gulf of Mexico, provides $11 billion in disaster relief for the States of Mississippi, Louisiana, and Alabama. In the State of Mississippi, $300 million in grant assistance in the form of Community Development Block Grants (CDBGs) is expected to be designated for utilities within the state. Mississippi Power plans to apply for these CDBGs to offset the cost of storm recovery. Mississippi Power is also considering securitization of remaining unrecovered costs as provided for under legislation passed in the State of Mississippi in the first quarter of 2006. The final outcome of these matters cannot now be determined.

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     Also in December 2005, Mississippi Power submitted its annual PEP filing to the Mississippi PSC. Ordinarily, PEP limits annual rate increases to 4%; however, Mississippi Power requested that the Mississippi PSC approve a temporary change to allow it to exceed this cap as a result of the ongoing effects of Hurricane Katrina. Mississippi Power had requested a 5.05%, or $32 million, retail base rate increase to become effective in April 2006. Hearings were held in March 2006, and the full increase was approved by the Mississippi PSC on March 13, 2006.

Mirant Matters

Mirant was an energy company with businesses that included independent power projects and energy trading and risk management companies in the U.S. and selected other countries. It was a wholly-owned subsidiary of Southern Company until its initial public offering in October 2000. In April 2001, Southern Company completed a spin-off to its shareholders of its remaining ownership, and Mirant became an independent corporate entity. In July 2003, Mirant filed for voluntary reorganization under Chapter 11 of the Bankruptcy Code. See Note 3 to the financial statements of Southern Company under “Mirant Matters — Mirant Bankruptcy” in Item 8 of the Form 10-K for information regarding Southern Company’s contingent liabilities associated with Mirant, including guarantees of contractual commitments, litigation, and joint and several liabilities in connection with the consolidated federal income tax return.

Mirant Securities Litigation

See Note 3 to the financial statements of Southern Company under “Mirant Matters — Mirant Securities Litigation” in Item 8 of theForm 10-K for information regarding a class action lawsuit that several Mirant shareholders (plaintiffs) originally filed against Mirant and certain Mirant officers in May 2002. In November 2002, Southern Company, certain former and current senior officers of Southern Company, and 12 underwriters of Mirant’s initial public offering were added as defendants. During Mirant’s Chapter 11 proceeding, the securities litigation was stayed, with the exception of limited discovery. Since Mirant’s plan of reorganization has become effective, the stay has been lifted, and activity has resumed. On March 24, 2006, the plaintiffs filed a Motion for Reconsideration requesting that the court vacate that portion of its July 14, 2003 order dismissing the plaintiffs’ claims based upon Mirant’s alleged improper energy trading and marketing activities involving the California energy market. Southern Company and the other defendants have opposed the plaintiffs’ motion. The plaintiffs have also stated that they intend to request that the court grant leave for them to amend the complaint to add allegations based upon claims asserted against Southern Company in the Mirant bankruptcy litigation. See Note 3 to the financial statements of Southern Company under “Mirant Matters — Mirant Bankruptcy Litigation” in Item 8 of the Form 10-K for additional information. The ultimate outcome of these matters cannot be determined at this time.

Southern Company Employee Savings Plan Litigation

See Note 3 to the financial statements of Southern Company under “Mirant Matters — Southern Company Employee Savings Plan Litigation” in Item 8 of the Form 10-K for information related to the class action complaint filed under ERISA in June 2004, and amended in December 2004 and November 2005, on behalf of a purported class of participants in or beneficiaries of The Southern Company Employee Savings Plan at any time since April 2, 2001 and whose plan accounts included investments in Mirant common stock. In April 2006, the U.S. District Court for the Northern District of Georgia granted summary judgment in favor of Southern Company and all individually named defendants in the case. The plaintiff has filed an appeal of the ruling. The final outcome of this matter cannot be determined at this time.

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Income Tax Matters

Leveraged Lease Transactions

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Income Tax Matters - Leveraged Lease Transactions” of Southern Company in Item 7 and Note 3 to the financial statements of Southern Company under “Income Tax Matters — Leveraged Lease Transactions” in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under “Income Tax Matters” for information regarding IRS challenges to Southern Company’s transactions related to international leveraged leases that could have material impacts on Southern Company’s financial statements. The FASB has recently proposed changes to the accounting for both leveraged leases and uncertain tax positions that may be effective beginning in 2007. If approved as proposed, these changes could require Southern Company to reflect the tax deductions that the IRS is challenging as currently payable on the balance sheet and to change the timing of income recognized under the leases, including a cumulative effect upon adoption of the change. For the lease settled with the IRS in February 2005, Southern Company estimates such cumulative effect would reduce Southern Company’s net income by approximately $16 million. The impact of these proposed changes related to the remaining three lease transactions would be dependent on the outcome of pending litigation, but could be significant, and potentially material, to Southern Company’s net income. The ultimate outcome of these matters cannot now be determined.

Synthetic Fuel Tax Credits

As discussed in MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Income Tax Matters — Synthetic Fuel Tax Credits” of Southern Company in Item 7 of the Form 10-K, Southern Company has investments in two entities that produce synthetic fuel and receive tax credits under Section 45K (formerly Section 29) of the IRC. In accordance with Section 45K of the IRC, these tax credits are subject to limitation as the annual average price of oil (as determined by the DOE) increases over a specified, inflation-adjusted dollar amount published in the spring of the subsequent year. Southern Company, along with its partners in these investments, will continue to monitor oil prices. Any indicated potential limitation on these credits could affect either the timing or the amount of the credit recognition and could also require an impairment analysis of these investments by Southern Company. Reserves against these tax credits of $17 million have been recorded in the first quarter 2006 due to projected phase-outs of the credits in 2006 as a result of current and projected future oil prices. See Note (J) to the Condensed Financial Statements herein for additional information regarding the impact of these reserves on the effective tax rate.

Other Matters

On March 16, 2006, a subsidiary of the Southern Company entered into a development agreement with Duke Energy Corporation (Duke) to evaluate the potential construction of a new two-unit nuclear plant at a jointly owned site in Cherokee County, South Carolina. If constructed, Southern Company would own an interest in Unit 1, representing approximately five hundred megawatts. Duke will be the developer and licensed operator of any plant built at the site.

     Southern Company is subject to certain claims and legal actions arising in the ordinary course of business. In addition, Southern Company’s business activities are subject to extensive governmental regulation related to public health and the environment. Litigation over environmental issues and claims of various types, including property damage, personal injury, and citizen enforcement of environmental requirements such as opacity and other air quality standards, 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. The ultimate outcome of such pending or potential litigation against Southern Company and its subsidiaries cannot be predicted at this time; however, for current proceedings not specifically reported herein or in Note 3 to the

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financial statements of Southern Company in Item 8 of the Form 10-K, management does not anticipate that the liabilities, if any, arising from such current proceedings would have a material adverse effect on Southern Company’s financial statements.

     See the Notes to the Condensed Financial Statements herein for discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Southern Company prepares its consolidated financial statements in accordance with accounting principles generally accepted in the United States. Significant accounting policies are described in Note 1 to the financial statements of Southern Company in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on Southern Company’s results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. Also see MANAGEMENT’S DISCUSSION AND ANALYSIS — ACCOUNTING POLICIES - “Application of Critical Accounting Policies and Estimates” of Southern Company in Item 7 of the Form 10-K for a complete discussion of Southern Company’s critical accounting policies and estimates related to Electric Utility Regulation, Contingent Obligations, and Unbilled Revenues.

New Accounting Standards

On January 1, 2006, Southern Company adopted FASB Statement No. 123(R), “Share-Based Payment,” using the modified prospective method. This statement requires that compensation cost relating to share-based payment transactions be recognized in the financial statements. That cost will be measured based on the grant date fair value of the equity or liability instruments issued. Although the compensation expense required under the revised statement differs slightly, the impacts on Southern Company’s financial statements are similar to the pro forma disclosures previously included in Note 1 to the financial statements of Southern Company under “Stock Options” in Item 8 of the Form 10-K and in Note (C) to the Condensed Financial Statements herein. Total pre-tax compensation cost related to non-vested awards not yet recognized is expected to be approximately $18 million over the remaining three-year service period.

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FINANCIAL CONDITION AND LIQUIDITY

Overview

Net cash flow from operating activities totaled $58 million for the first three months of 2006, compared to $171 million for the corresponding period in 2005. The $113 million decrease is primarily due to discontinued operations associated with the sale of Southern Company Gas assets, and increases in fuel and storm damage costs. For additional information regarding the sale of Southern Company Gas assets, see Note (B) to the Condensed Financial Statements herein under “SOUTHERN COMPANY GAS SALE.” Gross property additions to utility plant were $565 million in the first three months of 2006. The majority of funds needed for gross property additions since 2000 has been provided from operating activities.

     Significant balance sheet changes include a $383 million increase in long-term debt for the first three months of 2006 primarily for general corporate purposes. Property, plant, and equipment increased $162 million during the first quarter of 2006.

     The market price of Southern Company’s common stock at March 31, 2006 was $32.77 per share and the book value was $14.45 per share, representing a market-to-book ratio of 227%, compared to $34.53, $14.42, and 240%, respectively, at the end of 2005. The dividend for the first quarter 2006 was $0.3725 per share compared to $0.3575 per share in the first quarter 2005. In April 2006, the dividend was increased to $0.3875 per share for the dividend payable in June 2006.

     Southern Company, the retail operating companies, Southern Power, and SCS have each maintained investment grade ratings from the major rating agencies.

Capital Requirements and Contractual Obligations

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY —“Capital Requirements and Contractual Obligations” of Southern Company in Item 7 of the Form 10-K for a description of Southern Company’s capital requirements for its construction program and other funding requirements associated with scheduled maturities of long-term debt, as well as the related interest, preferred and preference stock dividends, leases, trust funding requirements, and other purchase commitments. Approximately $894 million will be required by March 31, 2007 for redemptions and maturities of long-term debt.

Sources of Capital

Southern Company intends to meet its future capital needs through internal cash flow and external security issuances. Equity capital can be provided from any combination of Southern Company’s stock plans, private placements, or public offerings. The amounts and timing of additional equity capital to be raised will be contingent on Southern Company’s investment opportunities. The retail operating companies and Southern Power plan to obtain the funds required for construction and other purposes from sources similar to those used in the past, which were primarily from operating cash flows, security issuances, and term loan and short-term borrowings. Gulf Power and Mississippi Power are considering other financing options for storm recovery costs. However, the amount, type, and timing of any financings, if needed, will depend upon prevailing market conditions, regulatory approval, and other factors. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Sources of Capital” of Southern Company in Item 7 of the Form 10-K for additional information.

     Southern Company’s current liabilities frequently exceed current assets because of the continued use of short-term debt as a funding source to meet cash needs as well as scheduled maturities of long-term debt. To meet short-term cash needs and contingencies, the Southern Company system had at March 31, 2006 approximately $301 million of cash and cash equivalents and approximately $3.3 billion of unused credit arrangements with banks, of which $810 million expire in 2006 and $2.5 billion expire in 2007 and beyond. Of

23

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

the facilities maturing in 2006, $311 million contain provisions allowing one-year term loans executable at the expiration date and $228 million contain provisions allowing two-year term loans executable at the expiration date. These unused credit arrangements also provide liquidity support to variable rate pollution control bonds and commercial paper programs. Southern Company expects to renew its credit facilities, as needed, prior to expiration. See Note 6 to the financial statements of Southern Company under “Bank Credit Arrangements” in Item 8 of the Form 10-K for additional information. The retail operating companies may also meet short-term cash needs through a Southern Company subsidiary organized to issue and sell commercial paper and extendible commercial notes at the request and for the benefit of each of the retail operating companies. At March 31, 2006, the Southern Company system had outstanding commercial paper of $1.4 billion, $225 million in bank notes, and extendible commercial notes of $44 million. Management believes that the need for working capital can be adequately met by utilizing commercial paper programs and lines of credit without maintaining large cash balances.

Off-Balance Sheet Financing Arrangements

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Off-Balance Sheet Financing Arrangements” of Southern Company in Item 7 and Note 7 to the financial statements of Southern Company under “Operating Leases” in Item 8 of the Form 10-K for information related to Mississippi Power’s lease of a combined cycle generating facility at Plant Daniel.

Credit Rating Risk

Southern Company does not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change to BBB and Baa2, or BBB- or Baa3 or below. These contracts are primarily for physical electricity purchases and sales. At March 31, 2006, the maximum potential collateral requirements at a BBB and Baa2 rating were approximately $9 million and at a BBB- or Baa3 rating were approximately $229 million. The maximum potential collateral requirements at a rating below BBB- or Baa3 were approximately $586 million. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. Southern Company’s operating subsidiaries are also party to certain derivative agreements that could require collateral and/or accelerated payment in the event of a credit rating change to below investment grade for Alabama Power and/or Georgia Power. These agreements are primarily for natural gas price risk management activities. At March 31, 2006, Southern Company’s total exposure to these types of agreements was approximately $11 million.

Market Price Risk

Southern Company’s market risk exposures relative to interest rate changes have not changed materially compared with the December 31, 2005 reporting period. In addition, Southern Company is not aware of any facts or circumstances that would significantly affect such exposures in the near term.

     Due to cost-based rate regulations, the retail operating companies have limited exposure to market volatility in interest rates, commodity fuel prices, and prices of electricity. In addition, Southern Power’s exposure to market volatility in commodity fuel prices and prices of electricity is limited because its long-term sales contracts shift substantially all fuel cost responsibility to the purchaser. To mitigate residual risks relative to movements in electricity prices, the retail operating companies and Southern Power enter into fixed-price contracts for the purchase and sale of electricity through the wholesale electricity market and, to a lesser extent, into similar contracts for natural gas purchases. The retail operating companies have implemented fuel-hedging programs at the instruction of their respective state PSCs.

24

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     The fair value of derivative energy contracts at March 31, 2006 was as follows:

	First Quarter
	2006
	Changes
	Fair Value
	(in millions)
Contracts beginning of period	$	100.5
Contracts realized or settled		(16.0	)
New contracts at inception		—
Changes in valuation techniques		—
Current period changes (a)		(119.5	)
Contracts at March 31, 2006	$	(35.0	)

(a) Current period changes also include the changes in fair value of new contracts entered into during the period.

	Source of March 31, 2006
	Valuation Prices
	Total			Maturity
	Fair Value			Year 1			1-3 Years
	(in millions)
Actively quoted	$	(35.1	)	$	(59.2	)	$	24.1
External sources		0.1			0.1			—
Models and other methods		—			—			—
Contracts at March 31, 2006	$	(35.0	)	$	(59.1	)	$	24.1

     Unrealized gains and losses from mark-to-market adjustments on derivative contracts related to the retail operating companies’ fuel hedging programs are recorded as regulatory assets and liabilities. Realized gains and losses from these programs are included in fuel expense and are recovered through the retail operating companies’ fuel cost recovery clauses. In addition, unrealized gains and losses on energy-related derivatives used by Southern Power to hedge anticipated purchases and sales are deferred in other comprehensive income. Gains and losses on derivative contracts that are not designated as hedges are recognized in the income statement as incurred. At March 31, 2006, the fair value gain/(loss) of derivative energy contracts was reflected in the financial statements as follows:

	Amounts
	(in millions)
Regulatory assets, net	$	(35.3	)
Accumulated other comprehensive loss		(0.1	)
Net income		0.4
Total fair value loss	$	(35.0	)

     Unrealized pre-tax gains and losses recognized in income were not material for any period presented.

     For additional information, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Market Price Risk” of Southern Company in Item 7 and Notes 1 and 6 to the financial statements of Southern Company under “Financial Instruments” in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein.

Financing Activities

In the first three months of 2006, Southern Company and its subsidiaries issued $800 million of senior notes, settled $600 million notional amount of related interest rate hedges at a gain of $18 million, and issued $14 million of common stock, including treasury stock, through employee and director stock plans. The proceeds

25

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

were primarily used to refund senior notes and to fund ongoing construction projects. The remainder was used to repay short-term indebtedness. The hedge gain will be deferred in other comprehensive income and amortized to income over a 10-year period. See Southern Company’s Condensed Consolidated Statements of Cash Flows herein for further details on financing activities during the first three months of 2006.

     In January 2006, Southern Company’s program to repurchase shares of stock to offset issuances under the Southern Company’s stock compensation plans was discontinued.

     In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Southern Company and its subsidiaries plan to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

26

PART I

Item 3. Quantitative And Qualitative Disclosures About Market Risk.

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Market Price Risk” herein for each registrant and Notes 1 and 6 to the financial statements of each registrant under “Financial Instruments” in Item 8 of the Form 10-K. Also, see Note (F) to the Condensed Financial Statements herein for information relating to derivative instruments.

Item 4. Controls and Procedures.

     (a) Evaluation of disclosure controls and procedures.

     As of the end of the period covered by this quarterly report, Southern Company, the retail operating companies, and Southern Power conducted separate evaluations under the supervision and with the participation of each company’s management, including the Chief Executive Officer and the Chief Financial Officer, of the effectiveness of the design and operation of the disclosure controls and procedures (as defined in Sections 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934). Based upon these evaluations, the Chief Executive Officer and the Chief Financial Officer, in each case, concluded that the disclosure controls and procedures are effective in alerting them in a timely manner to material information relating to their company (including its consolidated subsidiaries, if any) required to be included in periodic filings with the SEC.

     (b) Changes in internal controls.

Southern Company, Alabama Power, Georgia Power, Gulf Power, Mississippi Power, and Southern Power

     There have been no changes in Southern Company’s, Alabama Power’s, Georgia Power’s, Gulf Power’s, Mississippi Power’s, or Southern Power’s internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934) during the first quarter of 2006 that have materially affected or are reasonably likely to materially affect Southern Company’s, Alabama Power’s, Georgia Power’s, Gulf Power’s, Mississippi Power’s, or Southern Power’s internal control over financial reporting.

Savannah Electric

     During the first quarter 2006, Savannah Electric transferred responsibility for certain internal control procedures related to accounting for revenue and accounts payable transactions to Georgia Power and accounting for tax transactions to SCS. Savannah Electric continues to review such accounting transactions and maintains overall financial reporting responsibility; however, the transfer of these control procedures constitutes a change in Savannah Electric’s internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934) that has materially affected or is reasonably likely to materially affect Savannah Electric’s internal control over financial reporting.

27

ALABAMA POWER COMPANY

28

ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Revenues:
Retail revenues	$	802,209		$	709,086
Sales for resale —
Non-affiliates		146,354			114,414
Affiliates		79,315			107,286
Other revenues		44,829			38,950
Total operating revenues		1,072,707			969,736
Operating Expenses:
Fuel		341,767			299,820
Purchased power —
Non-affiliates		22,086			23,866
Affiliates		56,665			48,298
Other operations		169,013			146,290
Maintenance		109,500			123,554
Depreciation and amortization		109,862			108,491
Taxes other than income taxes		65,657			62,549
Total operating expenses		874,550			812,868
Operating Income		198,157			156,868
Other Income and (Expense):
Allowance for equity funds used during construction		5,529			5,654
Interest income		4,174			3,568
Interest expense, net of amounts capitalized		(53,219	)		(46,307	)
Interest expense to affiliate trusts		(4,059	)		(4,059	)
Other income (expense), net		(9,005	)		(2,805	)
Total other income and (expense)		(56,580	)		(43,949	)
Earnings Before Income Taxes		141,577			112,919
Income taxes		53,363			13,445
Net Income		88,214			99,474
Dividends on Preferred Stock		6,072			6,072
Net Income After Dividends on Preferred Stock	$	82,142		$	93,402

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Net Income After Dividends on Preferred Stock	$	82,142		$	93,402
Other comprehensive income (loss):
Changes in fair value of qualifying hedges, net of tax of $1,473 and $(713), respectively		2,423			(1,172	)
Reclassification adjustment for amounts included in net income, net of tax of $(1,006) and $66, respectively		(1,654	)		108
COMPREHENSIVE INCOME	$	82,911		$	92,338

     The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

29

ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Activities:
Net income	$	88,214		$	99,474
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization		129,238			127,300
Deferred income taxes and investment tax credits, net		(43,904	)		64
Deferred revenues		(559	)		(3,555	)
Allowance for equity funds used during construction		(5,529	)		(5,654	)
Pension, postretirement, and other employee benefits		(292	)		(3,431	)
Stock option expense		3,583			—
Tax benefit of stock options		111			5,302
Hedge settlements		18,006			(19,942	)
Storm damage accounting order		—			45,000
Other, net		1,271			42
Changes in certain current assets and liabilities —
Receivables		111,212			44,163
Fossil fuel stock		(32,192	)		(26,299	)
Materials and supplies		7,161			(9,039	)
Other current assets		(21,978	)		(11,661	)
Accounts payable		(152,217	)		(102,808	)
Accrued taxes		103,107			(27,128	)
Accrued compensation		(66,139	)		(45,701	)
Other current liabilities		25,325			36,423
Net cash provided from operating activities		164,418			102,550
Investing Activities:
Property additions		(228,402	)		(192,128	)
Nuclear decommissioning trust fund purchases		(72,384	)		(62,487	)
Nuclear decommissioning trust fund sales		72,384			62,487
Cost of removal net of salvage		(11,839	)		(8,824	)
Other		(5,292	)		(2,203	)
Net cash used for investing activities		(245,533	)		(203,155	)
Financing Activities:
Decrease in notes payable, net		(315,278	)		—
Proceeds —
Senior notes		800,000			250,000
Gross excess tax benefit of stock options		217			—
Redemptions —
Senior notes		(170,000	)		—
Payment of preferred stock dividends		(6,070	)		(4,742	)
Payment of common stock dividends		(110,150	)		(102,475	)
Other		(16,505	)		(2,345	)
Net cash provided from financing activities		182,214			140,438
Net Change in Cash and Cash Equivalents		101,099			39,833
Cash and Cash Equivalents at Beginning of Period		22,472			79,711
Cash and Cash Equivalents at End of Period	$	123,571		$	119,544
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $2,423 and $2,078 capitalized for 2006 and 2005, respectively)	$	35,993		$	26,375
Income taxes (net of refunds)	$	(10,989	)	$	23,154

     The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

30

ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Assets	2006			2005
	(in thousands)
Current Assets:
Cash and cash equivalents	$	123,571		$	22,472
Receivables —
Customer accounts receivable		273,322			275,702
Unbilled revenues		82,730			95,039
Under recovered regulatory clause revenues		115,486			132,139
Other accounts and notes receivable		43,230			50,008
Affiliated companies		59,130			77,304
Accumulated provision for uncollectible accounts		(8,157	)		(7,560	)
Fossil fuel stock, at average cost		147,271			102,420
Vacation pay		44,985			44,893
Materials and supplies, at average cost		224,597			244,417
Prepaid expenses		86,184			58,845
Other regulatory assets		72,858			43,621
Other		22,459			54,885
Total current assets		1,287,666			1,194,185
Property, Plant, and Equipment:
In service		15,451,825			15,300,346
Less accumulated provision for depreciation		5,416,578			5,313,731
		10,035,247			9,986,615
Nuclear fuel, at amortized cost		126,078			127,199
Construction work in progress		523,939			469,018
Total property, plant, and equipment		10,685,264			10,582,832
Other Property and Investments:
Equity investments in unconsolidated subsidiaries		47,111			46,913
Nuclear decommissioning trusts, at fair value		478,961			466,963
Other		40,482			41,457
Total other property and investments		566,554			555,333
Deferred Charges and Other Assets:
Deferred charges related to income taxes		384,994			388,634
Prepaid pension costs		521,211			515,281
Deferred under recovered regulatory clause revenues		131,426			186,864
Other regulatory assets		112,124			122,378
Other		149,062			144,400
Total deferred charges and other assets		1,298,817			1,357,557
Total Assets	$	13,838,301		$	13,689,907

     The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

31

ALABAMA POWER COMPANY
CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Liabilities and Stockholder's Equity	2006			2005
	(in thousands)
Current Liabilities:
Securities due within one year	$	376,645		$	546,645
Notes payable		—			315,278
Accounts payable —
Affiliated		115,344			190,744
Other		187,122			266,174
Customer deposits		58,877			56,709
Accrued taxes —
Income taxes		120,713			63,844
Other		50,462			31,692
Accrued interest		61,753			46,018
Accrued vacation pay		37,646			37,646
Accrued compensation		26,645			92,784
Other		87,709			72,991
Total current liabilities		1,122,916			1,720,525
Long-term Debt		4,356,731			3,560,186
Long-term Debt Payable to Affiliated Trusts		309,279			309,279
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes		2,052,072			2,070,746
Deferred credits related to income taxes		100,744			101,678
Accumulated deferred investment tax credits		194,584			196,585
Employee benefit obligations		216,383			208,663
Asset retirement obligations		453,459			446,268
Other cost of removal obligations		580,758			600,104
Other regulatory liabilities		193,669			194,135
Other		23,260			23,966
Total deferred credits and other liabilities		3,814,929			3,842,145
Total Liabilities		9,603,855			9,432,135
Preferred Stock		465,046			465,046
Common Stockholder’s Equity:
Common stock, par value $40 per share —
Authorized - 15,000,000 shares
Outstanding - 9,250,000 shares		370,000			370,000
Paid-in capital		1,998,967			1,995,056
Retained earnings		1,411,138			1,439,144
Accumulated other comprehensive loss		(10,705	)		(11,474	)
Total common stockholder’s equity		3,769,400			3,792,726
Total Liabilities and Stockholder’s Equity	$	13,838,301		$	13,689,907

     The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

32

ALABAMA POWER COMPANY

MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2006 vs. FIRST QUARTER 2005

OVERVIEW

Alabama Power operates as a vertically integrated utility providing electricity to retail customers within its traditional service area located within the State of Alabama and to wholesale customers in the Southeast. Many factors affect the opportunities, challenges, and risks of Alabama Power’s business of selling electricity. These factors include the ability to maintain a stable regulatory environment, to achieve energy sales growth while containing costs, and to recover rising costs related to growing demand and increasingly stringent environmental standards.

     Alabama Power continues to focus on several key performance indicators. These indicators include customer satisfaction, plant availability, system reliability, and net income. For additional information on these indicators, see MANAGEMENT’S DISCUSSION AND ANALYSIS — OVERVIEW — “Key Performance Indicators” of Alabama Power in Item 7 of the Form 10-K.

RESULTS OF OPERATIONS

Earnings

Alabama Power’s net income after dividends on preferred stock for the first quarter 2006 was $82.1 million compared to $93.4 million for the corresponding period of 2005. Earnings in the first quarter 2006 decreased by $11.3 million, or 12.1%. Excluding the offsetting natural disaster reserve impacts recorded in the first quarter 2005 (see MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Natural Disaster Cost Recovery” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “Retail Regulatory Matters — Natural Disaster Cost Recovery” in Item 8 of the Form 10-K), the decrease in earnings was primarily due to increases in other operations expense, scheduled plant maintenance, interest expense, and the proposed consent decree agreement with the EPA (as described in “Other income (expense), net” below), partially offset by a 1.2% increase in retail rates that took effect January 1, 2006 under Alabama Power’s new environmental rate order approved by the Alabama PSC. See Note 3 to the financial statements of Alabama Power under “Retail Regulatory Matters” in Item 8 of the Form 10-K for additional information on Alabama Power’s rates.

     Significant income statement items appropriate for discussion include the following:

	Increase (Decrease)
	First Quarter
	(in thousands)			%
Retail revenues	$	93,123			13.1
Sales for resale-non-affiliates		31,940			27.9
Sales for resale-affiliates		(27,971	)		(26.1	)
Other revenues		5,879			15.1
Fuel expense		41,947			14.0
Purchased power-non-affiliates		(1,780	)		(7.5	)
Purchased power-affiliates		8,367			17.3
Other operations expense		22,723			15.5
Maintenance expense		(14,054	)		(11.4	)
Interest expense, net of amounts capitalized		6,912			14.9
Other income (expense), net		6,200			221.0
Income taxes		39,918			296.9

33

ALABAMA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Retail revenues. The chart below reflects the primary drivers of the 13.1% increase in retail revenues in the first quarter 2006 compared to the same period in the prior year. Energy cost recovery revenues and other cost recovery revenues, which include the recovery of costs associated with PPAs certificated by the Alabama PSC (Rate CNP) and revenues associated with the replenishment of Alabama Power’s natural disaster reserve, generally do not affect net income. Excluding these revenues, retail revenues increased by $31.2 million, or 6.1%, for the first quarter 2006 when compared to the corresponding period in 2005. This increase was primarily due to 1.1% increase in KWH energy sales for the first quarter of 2006, as well as the retail rate increase implemented in January 2006 to recover environmental costs. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Retail Rate Adjustments” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “Retail Regulatory Matters —Rate CNP” in Item 8 of the Form 10-K. KWH energy sales to residential and commercial customers increased 1.5% and 2.0%, respectively, for the first quarter 2006 when compared to the corresponding period in 2005, primarily due to increased sales growth. KWH energy sales to industrial customers increased 0.4% for the first quarter 2006 when compared to the first quarter of 2005 due to increased sales demand in the pulp and paper, automotive, and primary metals sectors.

     Details of retail revenues are as follows:

	First Quarter
	2006
	(in millions)			% change
Retail — prior year	$	709
Change in —
Base rates		9			1.3
Sales growth		23			3.3
Weather		(1	)		(0.1	)
Energy cost recovery		51			7.1
Other cost recovery		11			1.5
Retail — current year	$	802			13.1	%

     Sales for resale — non-affiliates. Energy sales to non-affiliates will vary depending on the market cost of available energy compared to the cost of Alabama Power and Southern Company system owned generation, demand for energy within the Southern Company service territory, and availability of Southern Company system generation. In the first quarter 2006, revenues from sales for resale to non-affiliates increased $31.9 million when compared to the same period in 2005 primarily due to a 35.8% increase in price partially offset by 5.8% decrease in KWH sales to non-affiliates in the first quarter 2006. The 2006 price increases are generally the result of increased costs for both coal and natural gas. These transactions did not have a significant impact on earnings since energy is usually sold at variable cost.

     Sales for resale — affiliates.Energy sales to affiliated companies within the Southern Company system vary from period to period depending on demand and the availability and cost of generating resources at each company. These sales are made in accordance with the IIC, as approved by the FERC. In the first quarter 2006, revenues from sales for resale to affiliates decreased $28.0 million when compared to the same period in 2005 primarily due to a 28.5% decrease in KWH sales to affiliates as a result of a decrease in the availability of Alabama Power’s generating resources for such sales due to increased sales growth in Alabama Power’s service territory during the first quarter of 2006 and scheduled maintenance at Alabama Power’s generating facilities. These transactions did not have a significant impact on earnings since energy is generally sold at marginal cost.

34

ALABAMA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Other revenues.The $5.9 million increase in other revenues for the first quarter 2006 when compared to the corresponding period in 2005 is primarily attributed to a $4.3 million increase in revenues from cogeneration steam facilities due to increased fuel revenue resulting from higher natural gas prices (since cogeneration steam fuel revenues are generally offset by fuel expense, these revenues do not have a significant impact on earnings) and a $1.4 million increase in rent from electric property.

     Fuel expense, purchased power — non-affiliates, and purchased power — affiliates.Total fuel and purchased power expense increased $48.5 million in the first quarter 2006 when compared to the corresponding period in 2005 primarily due to a $75.6 million increase in the cost of fuel offset by a $27.1 million decrease related to fewer KWHs generated and purchased. Details of the individual components follow.

Fuel expense increased $41.9 million in the first quarter 2006 when compared to the corresponding period in 2005 primarily due to a 16.3% increase in the average cost of coal offset by a 6.6% decrease in generation from coal-fired generation facilities and a 28.8% increase in natural gas prices offset by a 1.1% decrease in generation from gas-fired facilities. Since energy expenses are generally offset by energy revenues, these expenses do not have a significant impact on earnings.

Purchased power from non-affiliates will vary depending on market cost of available energy being lower than Southern Company system generated energy, demand for energy within the service territory, and availability of Southern Company system generation. In the first quarter 2006, purchased power from non-affiliates decreased $1.8 million when compared to the same period in 2005 primarily due to a 4.1% decrease in the number of kilowatt-hours of energy purchased. These transactions did not have a significant impact on earnings since energy purchases are generally offset by energy revenues through Alabama Power’s energy cost recovery clause.

Purchased power from affiliates will vary depending on demand and the availability and cost of generating resources at each company within the Southern Company system. These purchases are made in accordance with the IIC, as approved by the FERC. Purchased power from affiliates increased $8.4 million in the first quarter 2006 compared to the same period in 2005 due to a 17.3% increase in price primarily due to an increase in fuel costs offset by a 5.4% decrease in the amount of energy purchased. These transactions did not have a significant impact on earnings since energy purchases are generally offset by energy revenues through Alabama Power’s energy cost recovery clause.

     Other operations expense.Other operations expense increased $22.7 million in the first quarter 2006 when compared to the same period in 2005 primarily due to an $11.7 million increase in administrative and general expenses related to a $4.4 million increase in employee benefits and a $2.9 million increase in outside service expenses. In addition, other operations expense increased due to a $2.1 million increase in steam power expense related primarily to outage costs at various coal-fired facilities and other miscellaneous steam expense, a $1.6 million increase in transmission expense associated with external electric purchases, a $1.3 million increase in customer accounts expense mainly associated with information technology cost, and a $1.1 million increase in distribution expense.

     Maintenance expense.Maintenance expense decreased $14.1 million in the first quarter 2006 when compared to the same period in 2005 primarily due the recording of $45 million additional transmission and distribution expense in 2005. These costs were a result of the Alabama PSC accounting order to offset the costs of the damage from Hurricane Ivan in September 2004 and to restore a balance in the natural disaster reserve. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Natural Disaster Cost Recovery” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “Natural Disaster Cost Recovery” in Item 8 of Form 10-K. Excluding the natural

35

ALABAMA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

disaster reserve impacts of such accounting order, maintenance expense increased $30.9 million in the first quarter 2006 when compared to the same period in 2005. This increase was due to a $14.3 million increase in steam expense associated with outage maintenance cost at various coal-fired facilities, a $9.4 million increase in distribution expense primarily associated with the 2006 natural disaster reserve accrual and amortization of deferred storm expense and a $4.4 million increase in transmission expense primarily associated with the 2006 natural disaster reserve accrual, amortization of deferred storms expense, and maintenance of station equipment.

     Interest expense, net of amounts capitalized.The increase in interest expense, net of amounts capitalized during the first quarter 2006 when compared to the same period in 2005 primarily is the result of the issuance of additional senior notes in the first three months of 2006. For additional information, see FINANCIAL CONDITION AND LIQUIDITY — “Financing Activities” herein and in Item 7 of Alabama Power of the Form 10-K.

     Other income (expense), net.Other income, net decreased $6.2 million in the first quarter 2006 when compared to the first quarter 2005 due to a $5.0 million proposed settlement in April 2006 with the EPA in the NSR litigation. See FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Litigation” and Note (B) to the Condensed Financial Statements herein for additional information.

     Income taxes.Income tax expense increased $39.9 million in the first quarter 2006 when compared to the first quarter 2005. In accordance with the Alabama PSC accounting order described above, Alabama Power returned $27.7 million of regulatory liabilities related to deferred income taxes to its retail customers in 2005. The remainder of the increase in income tax expense in the first quarter 2006 compared to the same period in 2005 primarily reflects the $17.3 million tax effect of the additional maintenance expenses recorded under the accounting order in 2005. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Natural Disaster Cost Recovery” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “Retail Regulatory Matters — Natural Disaster Cost Recovery” in Item 8 of Form 10-K and Note (J) to the Condensed Financial Statements herein for additional information.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Alabama Power’s future earnings potential. The level of Alabama Power’s future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Alabama Power’s business of selling electricity. These factors include Alabama Power’s ability to maintain a stable regulatory environment that continues to allow for the recovery of all prudently incurred costs. Future earnings in the near term will depend, in part, upon growth in energy sales, which is subject to a number of factors. These factors include weather, competition, new energy contracts with neighboring utilities, energy conservation practiced by customers, the price of electricity, the price elasticity of demand, and the rate of economic growth in Alabama Power’s service area. For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL of Alabama Power in Item 7 of the Form 10-K.

Environmental Matters

Compliance costs related to the Clean Air Act and other environmental regulations could affect earnings if such costs cannot be fully recovered in rates on a timely basis. For additional information, including information on certain environmental litigation, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “Environmental Matters” in Item 8 of the Form 10-K.

36

ALABAMA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

New Source Review Litigation

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Actions” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K for additional information regarding a civil action brought by the EPA alleging that Alabama Power had violated the NSR provisions of the Clean Air Act and related state laws with respect to certain of its coal-fired generating facilities. On April 24, 2006, as a result of court-ordered mediation, the EPA filed, with the U.S. District Court for the Northern District of Alabama, statements designed to result in a judgment being entered in favor of Alabama Power on the claims related to Plants Barry, Gaston, Gorgas, and Greene County. In turn, Alabama Power agreed to the filing with the district court of a proposed consent decree that, upon such court’s approval, would require Alabama Power to pay $100,000 to resolve the EPA’s claim for a civil penalty related to alleged violations at Plant Miller. The proposed consent decree also formalizes specific emissions reductions to be accomplished by Alabama Power. These reductions are consistent with other Clean Air Act programs that require emissions reductions. Alabama Power further agreed to donate $4.9 million of sulfur dioxide emission allowances to a nonprofit charitable organization. As a result, Alabama Power recognized $5 million in other income (expense), net related to the proposed consent decree. The final resolution of these claims is dependent on further court action and subject to possible appeals, and therefore, cannot be determined at this time.

New Source Review Reform Rules

On October 20, 2005, the EPA published a proposed rule clarifying the test for determining when an emissions increase is subject to the NSR requirements. On March 17, 2006, the U.S. Court of Appeals for the District of Columbia Circuit vacated the EPA’s proposed rule which sought to clarify the scope of the existing Routine Maintenance, Repair, and Replacement Exclusion. Because this rule was not yet in effect, the court’s ruling is not anticipated to have any impact on Alabama Power. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Actions” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K for additional information.

FERC and Alabama PSC Matters

Market-Based Rate Authority

See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Market-Based Rate Authority” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “FERC Matters — Market-Based Rate Authority” in Item 8 of the Form 10-K for information on the FERC’s April 2004 order adopting a new interim analysis for measuring generation market power and a proceeding initiated by the FERC in December 2004 to assess Southern Company’s generation dominance within its retail service territory. Alabama Power has authorization from the FERC to sell power to non-affiliates at market-based prices. Alabama Power also has 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. On February 15, 2005, Southern Company submitted additional information related to generation dominance in its retail service territory. A hearing before an administrative law judge scheduled for March 2006 has been held in abeyance to allow the parties to explore settlement. Any new market-based rate transactions in its 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. The impact of such sales through March 31, 2006 is not expected to exceed $3.7 million for Alabama Power. The refund

37

ALABAMA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

period covers 15 months. In the event that the FERC’s default mitigation measures are ultimately applied, Alabama Power 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 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.

     In addition, in May 2005, the FERC initiated an investigation to determine whether Southern Company satisfies the other three parts of the FERC’s market-based rate analysis: transmission market power, barriers to entry, and affiliate abuse or reciprocal dealing. The FERC established a new 15-month refund period related to this expanded investigation. Any new market-based rate transactions involving any Southern Company subsidiary will be subject to refund to the extent the FERC orders lower rates as a result of this new investigation, with the refund period beginning July 19, 2005. The impact of such sales involving Alabama Power through March 31, 2006 is not expected to exceed $9.8 million, of which $2.9 million relates to sales inside the retail service territory discussed above. The FERC also directed that this expanded proceeding be held in abeyance pending the outcome of the proceeding on the IIC discussed below.

     Alabama Power believes that there is no meritorious basis for this proceeding and is vigorously defending itself in this matter. However, the final outcome of this matter, including any remedies to be applied in the event of an adverse ruling in this proceeding, cannot now be determined.

Intercompany Interchange Contract

Also in May 2005, the FERC initiated a new proceeding to examine (1) the provisions of the IIC among Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, Southern Power, and SCS, as agent, under the terms of which the power pool of Southern Company is operated, and, in particular, the propriety of the continued inclusion of Southern Power as a party to the IIC, (2) whether any parties to the IIC have violated the FERC’s standards of conduct applicable to utility companies that are transmission providers, and (3) whether Southern Company’s code of conduct defining Southern Power as a “system company” rather than a “marketing affiliate” is just and reasonable. In connection with the formation of Southern Power, the FERC authorized Southern Power’s inclusion in the IIC in 2000. The FERC also previously approved Southern Company’s code of conduct. The FERC order directs that the administrative law judge who presided over a proceeding involving approval of PPAs between Southern Power and Georgia Power and Savannah Electric be assigned to preside over the hearing in this proceeding and that the testimony and exhibits presented in that proceeding be preserved to the extent appropriate. Effective July 19, 2005, revenues from transactions under the IIC involving any Southern Company subsidiaries will be subject to refund to the extent the FERC orders any changes to the IIC. On April 11, 2006, Southern Company, Calpine Corporation, Coral Energy, and Dalton Utilities filed a settlement offer that would resolve the proceeding. The offer is pending before the FERC and does not require any refunds. However, because the offer is pending, the final outcome of this matter cannot now be determined.See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Intercompany Interchange Contract” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “FERC Matters — Intercompany Interchange Contract” in Item 8 of the Form 10-K for additional information.

Retail Fuel Cost Recovery

Alabama Power has established fuel cost recovery rates approved by the Alabama PSC. Alabama Power’s under recovered fuel costs as of March 31, 2006 totaled $219.5 million as compared to $285.1 million at December 31, 2005. Alabama Power increased its fuel billing factor in January 2006 in accordance with Rate ECR. Alabama Power will continue to monitor the under recovered fuel cost balance to determine if an additional adjustment to billing rates should be requested from the Alabama PSC. See MANAGEMENT’S

38

ALABAMA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Retail Fuel Cost Recovery” of Alabama Power in Item 7 and Note 3 to the financial statements of Alabama Power under “Retail Regulatory Matters — Fuel Cost Recovery” in Item 8 of the Form 10-K for additional information.

Other Matters

Alabama Power is subject to certain claims and legal actions arising in the ordinary course of business. In addition, Alabama Power’s business activities are subject to extensive governmental regulation related to public health and the environment. Litigation over environmental issues and claims of various types, including property damage, personal injury, and citizen enforcement of environmental requirements such as opacity and other air quality standards, 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. The ultimate outcome of such pending or potential litigation against Alabama Power cannot be predicted at this time; however, for current proceedings not specifically reported herein or in Note 3 to the financial statements of Alabama Power in Item 8 of the Form 10-K, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material adverse effect on Alabama Power’s financial statements.

     See Note (B) to the Condensed Financial Statements herein for discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Alabama Power prepares its financial statements in accordance with accounting principles generally accepted in the United States. Significant accounting policies are described in Note 1 to the financial statements of Alabama Power in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on Alabama Power’s results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT’S DISCUSSION AND ANALYSIS —ACCOUNTING POLICIES — “Application of Critical Accounting Policies and Estimates” of Alabama Power in Item 7 of the Form 10-K for a complete discussion of Alabama Power’s critical accounting policies and estimates related to Electric Utility Regulation, Contingent Obligations, and Unbilled Revenues.

New Accounting Standards

On January 1, 2006, Alabama Power adopted FASB Statement No. 123(R), “Share-Based Payment,” using the modified prospective method. This statement requires that compensation cost relating to share-based payment transactions be recognized in the financial statements. That cost will be measured based on the grant date fair value of the equity or liability instruments issued. Although the compensation expense required under the revised statement differs slightly, the impacts on Alabama Power’s financial statements are similar to the pro forma disclosures previously included in Note 1 to the financial statements of Alabama Power under “Stock Options” in Item 8 of the Form 10-K and in Note (C) to the Condensed Financial Statements herein. Total pre-tax compensation cost related to non-vested awards not yet recognized is expected to be approximately $2.6 million over the remaining three-year service period.

39

ALABAMA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FINANCIAL CONDITION AND LIQUIDITY

Overview

Alabama Power’s financial condition continued to be stable at March 31, 2006. Net cash flows from operating activities totaled $164.4 million for the first three months of 2006, compared to $102.5 million for the first three months of 2005. The $61.9 million increase in the first three months of 2006 relates to a decrease in under recovered fuel cost receivable due to higher recovery rates under a new fuel rate effective January 1, 2006 and an increase in the accrued tax liability. These positive changes were partially offset by a decrease in accounts payable resulting from increased spending accrued in the fourth quarter 2005 that were paid in the first quarter 2006 and a decrease in deferred income tax expense. The changes in the accrued tax liability and deferred income tax expense are due to the reversal of prior favorable timing differences. Property additions to utility plant were $228.4 million in the first three months of 2006 and are included in the balance sheets herein.

Capital Requirements and Contractual Obligations

See MANAGEMENT’S DISCUSSION AND ANALYSIS - FINANCIAL CONDITION AND LIQUIDITY - “Capital Requirements and Contractual Obligations” of Alabama Power in Item 7 of the Form 10-K for a description of Alabama Power’s capital requirements for its construction program, scheduled maturities of long-term debt, as well as related interest, preferred stock dividends, lease obligations, purchase commitments, and trust funding requirements. Approximately $377 million will be required through March 31, 2007 for redemptions and maturities of long-term debt.

Sources of Capital

Alabama Power plans to obtain the funds required for construction and other purposes from sources similar to those utilized in the past, which were primarily operating cash flows, with capital contributions from Southern Company, short-term debt, and external security issuances providing additional funds. However, the amount, type, and timing of any financings — if needed — will depend upon maintenance of adequate earnings, regulatory approval, prevailing market conditions, and other factors. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Sources of Capital” of Alabama Power in Item 7 of the Form 10-K for additional information.

     To meet short-term cash needs and contingencies, Alabama Power had at March 31, 2006 approximately $124 million of cash and cash equivalents, unused committed lines of credit of approximately $878 million (including $563 million of such lines which are dedicated to funding purchase obligations relating to variable rate pollution control bonds) and an extendible commercial note program. Of these credit facilities, $428 million will expire at various times during the remainder of 2006. $251 million of the credit facilities expiring in 2006 allow for the execution of one-year term loans. Alabama Power expects to renew its credit facilities, as needed, prior to expiration. See Note 6 to the financial statements of Alabama Power under “Bank Credit Arrangements” in Item 8 of the Form 10-K for additional information. Alabama Power may also meet short-term cash needs through a Southern Company subsidiary organized to issue and sell commercial paper and extendible commercial notes at the request and for the benefit of Alabama Power and other Southern Company subsidiaries. Alabama Power has regulatory authority for up to $1.4 billion of short-term borrowings. At March 31, 2006, Alabama Power had no commercial paper or extendible commercial notes outstanding. Management believes that the need for working capital can be adequately met by issuing commercial paper or utilizing lines of credit without maintaining large cash balances.

40

ALABAMA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Credit Rating Risk

Alabama Power does not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. However, Alabama Power, along with all members of the Southern Company power pool, is also party to certain derivative agreements that could require collateral and/or accelerated payment in the event of a credit rating change to below investment grade for it and/or Georgia Power. These agreements are primarily for natural gas price risk management activities. At March 31, 2006, Alabama Power’s total exposure to these types of agreements was approximately $11 million.

Market Price Risk

Alabama Power’s market risk exposures relative to interest rate changes have not changed materially compared with the December 31, 2005 reporting period. In addition, Alabama Power is not aware of any facts or circumstances that would significantly affect such exposures in the near term.

     Due to cost-based rate regulations, Alabama Power has limited exposure to market volatility in interest rates, commodity fuel prices, and prices of electricity. To mitigate residual risks relative to movements in electricity prices, Alabama Power enters into fixed-price contracts for the purchase and sale of electricity through the wholesale electricity market. Alabama Power has also implemented a retail fuel hedging program at the instruction of the Alabama PSC.

     The fair value of derivative energy contracts at March 31, 2006 was as follows:

	First Quarter
	2006
	Changes
	Fair Value
	(in thousands)
Contracts beginning of period	$	28,978
Contracts realized or settled		(5,917	)
New contracts at inception		—
Changes in valuation techniques		—
Current period changes (a)		(45,509	)
Contracts at March 31, 2006	$	(22,448	)

(a) Current period changes also include the changes in fair value of new contracts entered into during the period, if any.

	Source of March 31, 2006
	Valuation Prices
	Total			Maturity
	Fair Value			Year 1			1-3 Years
	(in thousands)
Actively quoted	$	(22,441	)	$	(29,477	)	$	7,036
External sources		(7	)		(7	)		—
Models and other methods		—			—			—
Contracts at March 31, 2006	$	(22,448	)	$	(29,484	)	$	7,036

41

ALABAMA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Unrealized gains and losses from mark-to-market adjustments on derivative contracts related to Alabama Power’s fuel hedging programs are recorded as regulatory assets and liabilities. Realized gains and losses from these programs are included in fuel expense and are recovered through Alabama Power’s fuel cost recovery clause. Gains and losses on derivative contracts that are not designated as hedges are recognized in the statements of income as incurred. At March 31, 2006, the fair value gain/(loss) of derivative energy contracts was reflected in the financial statements as follows:

	Amounts
	(in thousands)
Regulatory assets, net	$	(22,448	)
Accumulated other comprehensive income		—
Net income		—
Total fair value loss	$	(22,448	)

     Unrealized pre-tax gains (losses) on energy contracts recognized in income were not material for any period presented.

     For additional information, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Market Price Risk” of Alabama Power in Item 7 and Notes 1 and 6 to the financial statements of Alabama Power under “Financial Instruments” in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein.

Financing Activities

In January 2006, Alabama Power issued $100 million of Series EE 5.75% Senior Insured Quarterly Notes due January 15, 2036 and $200 million of Series FF 5.20% Senior Notes due January 15, 2016. Alabama Power settled interest rate swaps related to the transactions at a gain of $3 million, which was recorded in other comprehensive income. The gain will be amortized to interest expense over a 10-year period.

     In February 2006, Alabama Power issued $100 million of Series GG 5 7/8% Senior Notes due February 1, 2046 and $200 million of Series HH 5.10% Senior Notes due February 1, 2011. Alabama Power settled interest rate swaps related to the transactions at a gain of $15 million, which was recorded in other comprehensive income. The gain will be amortized to interest expense over a 10-year period.

     In February 2006, $170 million in aggregate principal amount of Series U 2.65% Senior Notes matured.

     In March 2006, Alabama Power issued $200 million of Series II 5.875% Senior Notes due March 15, 2046. The proceeds from this issuance, as well as those from the January and February 2006 senior note issuances, were used to repay a portion of Alabama Power’s outstanding short-term indebtedness and for other general corporate purposes, including Alabama Power’s continuing construction activities.

     Subsequent to March 31, 2006, a $26.5 million long-term security was redeemed and funded with a combination of temporary cash investments and short-term debt.

     In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Alabama Power plans to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

42

GEORGIA POWER COMPANY

43

GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Revenues:
Retail revenues	$	1,266,956		$	1,185,236
Sales for resale —
Non-affiliates		133,364			112,852
Affiliates		34,942			25,631
Other revenues		52,187			46,711
Total operating revenues		1,487,449			1,370,430
Operating Expenses:
Fuel		434,774			309,266
Purchased power —
Non-affiliates		56,555			52,974
Affiliates		190,519			220,004
Other operations		218,720			202,079
Maintenance		119,300			116,650
Depreciation and amortization		117,857			123,100
Taxes other than income taxes		67,145			60,759
Total operating expenses		1,204,870			1,084,832
Operating Income		282,579			285,598
Other Income and (Expense):
Allowance for equity funds used during construction		5,785			9,257
Interest income		316			471
Interest expense, net of amounts capitalized		(60,207	)		(50,420	)
Interest expense to affiliate trusts		(14,878	)		(14,878	)
Other income (expense), net		(994	)		(2,842	)
Total other income and (expense)		(69,978	)		(58,412	)
Earnings Before Income Taxes		212,601			227,186
Income taxes		79,944			84,654
Net Income		132,657			142,532
Dividends on Preferred Stock		1,010			168
Net Income After Dividends on Preferred Stock	$	131,647		$	142,364

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Net Income After Dividends on Preferred Stock	$	131,647		$	142,364
Other comprehensive income (loss):
Change in fair value of marketable securities, net of tax of $(97) and $75, respectively		(155	)		118
Changes in fair value of qualifying hedges, net of tax of $5,215 and $1,370, respectively		8,267			2,172
Reclassification adjustment for amounts included in net income, net of tax of $110 and $176, respectively		175			280
COMPREHENSIVE INCOME	$	139,934		$	144,934

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

44

GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Activities:
Net income	$	132,657		$	142,532
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization		138,694			142,765
Deferred income taxes and investment tax credits		145			59,414
Deferred expenses — affiliates		19,937			19,974
Allowance for equity funds used during construction		(5,785	)		(9,257	)
Pension, postretirement, and other employee benefits		(540	)		3,755
Stock option expense		3,708			—
Tax benefit of stock options		193			4,907
Other, net		1,263			(16,984	)
Changes in certain current assets and liabilities —
Receivables		126,023			(82,023	)
Fossil fuel stock		(47,256	)		(5,334	)
Materials and supplies		(19,347	)		1,430
Prepaid income taxes		61,519			17,892
Other current assets		(19,810	)		(11,064	)
Accounts payable		(220,939	)		(106,494	)
Accrued taxes		(80,585	)		(65,104	)
Accrued compensation		(107,191	)		(86,041	)
Other current liabilities		3,057			3,880
Net cash provided from (used for) operating activities		(14,257	)		14,248
Investing Activities:
Property additions		(206,588	)		(188,272	)
Nuclear decommissioning trust fund purchases		(100,167	)		(114,367	)
Nuclear decommissioning trust fund sales		93,287			105,668
Cost of removal net of salvage		(5,699	)		(4,696	)
Change in construction payables, net of joint owner portion		(22,325	)		(34,441	)
Other		447			6,188
Net cash used for investing activities		(241,045	)		(229,920	)
Financing Activities:
Increase in notes payable, net		341,043			339,693
Proceeds —
Senior notes		—			250,000
Capital contributions from parent company		231,000			—
Gross excess tax benefit of stock options		443			—
Redemptions —
Senior notes		(150,000	)		(250,000	)
Preferred stock		(14,569	)		—
Payment of preferred stock dividends		(12	)		(48	)
Payment of common stock dividends		(150,625	)		(139,025	)
Other		196			(9,725	)
Net cash provided from financing activities		257,476			190,895
Net Change in Cash and Cash Equivalents		2,174			(24,777	)
Cash and Cash Equivalents at Beginning of Period		10,636			33,497
Cash and Cash Equivalents at End of Period	$	12,810		$	8,720
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $2,419 and $3,709 capitalized for 2006 and 2005, respectively)	$	79,020		$	58,350
Income taxes (net of refunds)	$	(21,801	)	$	(492	)

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

45

GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Assets	2006			2005
	(in thousands)
Current Assets:
Cash and cash equivalents	$	12,810		$	10,636
Receivables —
Customer accounts receivable		363,099			418,154
Unbilled revenues		126,905			141,875
Under recovered regulatory clause revenues		519,833			454,683
Other accounts and notes receivable		70,757			110,397
Affiliated companies		23,144			84,597
Accumulated provision for uncollectible accounts		(8,091	)		(8,647	)
Fossil fuel stock, at average cost		228,995			181,739
Vacation pay		59,472			59,190
Materials and supplies, at average cost		343,297			323,908
Prepaid expenses		18,130			70,825
Other		99,952			50,248
Total current assets		1,858,303			1,897,605
Property, Plant, and Equipment:
In service		19,789,730			19,603,249
Less accumulated provision for depreciation		7,683,394			7,575,926
		12,106,336			12,027,323
Nuclear fuel, at amortized cost		143,838			134,798
Construction work in progress		558,808			563,155
Total property, plant, and equipment		12,808,982			12,725,276
Other Property and Investments:
Equity investments in unconsolidated subsidiaries		68,136			68,188
Nuclear decommissioning trusts, at fair value		516,815			486,591
Other		71,244			71,468
Total other property and investments		656,195			626,247
Deferred Charges and Other Assets:
Deferred charges related to income taxes		499,155			500,882
Prepaid pension costs		481,967			476,458
Deferred under recovered regulatory clause revenues		264,460			295,116
Other regulatory assets		317,701			330,483
Other		173,811			195,716
Total deferred charges and other assets		1,737,094			1,798,655
Total Assets	$	17,060,574		$	17,047,783

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

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GEORGIA POWER COMPANY
CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Liabilities and Stockholder's Equity	2006			2005
	(in thousands)
Current Liabilities:
Securities due within one year	$	2,765		$	167,317
Notes payable		608,785			267,743
Accounts payable —
Affiliated		116,788			285,019
Other		275,700			360,455
Customer deposits		136,427			129,293
Accrued taxes —
Income taxes		208,958			150,896
Other		84,731			204,778
Accrued interest		81,020			88,885
Accrued vacation pay		45,692			45,602
Accrued compensation		30,479			137,303
Other		160,113			120,312
Total current liabilities		1,751,458			1,957,603
Long-term Debt		4,178,567			4,179,218
Long-term Debt Payable to Affiliated Trusts		969,073			969,073
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes		2,719,487			2,730,303
Deferred credits related to income taxes		155,977			158,759
Accumulated deferred investment tax credits		284,653			287,726
Employee benefit obligations		368,446			358,137
Asset retirement obligations		637,173			627,465
Other cost of removal obligations		403,775			404,614
Other regulatory liabilities		87,029			97,015
Other		65,748			63,335
Total deferred credits and other liabilities		4,722,288			4,727,354
Total Liabilities		11,621,386			11,833,248
Common Stockholder’s Equity:
Common stock, without par value—
Authorized - 15,000,000 shares
Outstanding - 7,761,500 shares		344,250			344,250
Paid-in capital		2,878,356			2,643,012
Retained earnings		2,242,720			2,261,698
Accumulated other comprehensive loss		(26,138	)		(34,425	)
Total common stockholder’s equity		5,439,188			5,214,535
Total Liabilities and Stockholder’s Equity	$	17,060,574		$	17,047,783

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

47

GEORGIA POWER COMPANY

MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2006 vs. FIRST QUARTER 2005

OVERVIEW

Georgia Power operates as a vertically integrated utility providing electricity to retail customers within its traditional service area located within the State of Georgia and to wholesale customers in the Southeast. Many factors affect the opportunities, challenges, and risks of Georgia Power’s business of selling electricity. These factors include the ability to maintain a stable regulatory environment, to achieve energy sales growth while containing costs, and to recover rising costs related to growing demand and increasingly stringent environmental standards. In addition, fuel costs rose significantly during 2005 and the first quarter of 2006. Georgia Power has filed a request to increase its fuel recovery rate and will continue to work with the Georgia PSC to enable the timely recovery of these costs.

     On December 13, 2005, Savannah Electric entered into a merger agreement with Georgia Power under which Savannah Electric will merge into Georgia Power, with Georgia Power continuing as the surviving corporation, subject to the receipt of all required approvals. For additional information, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Merger” of Georgia Power in Item 7 and Note 3 to the financial statements of Georgia Power under “Retail Regulatory Matters — Merger” in Item 8 of the Form 10-K.

     Georgia Power continues to focus on several key performance indicators. These indicators include customer satisfaction, plant availability, system reliability, and net income. For additional information on these indicators, see MANAGEMENT’S DISCUSSION AND ANALYSIS — OVERVIEW — “Key Performance Indicators” of Georgia Power in Item 7 of the Form 10-K.

RESULTS OF OPERATIONS

Earnings

Georgia Power’s net income after dividends on preferred stock for the first quarter 2006 was $131.7 million compared to $142.4 million for the corresponding period in 2005. The $10.7 million, or 7.5% decrease, is primarily attributed to higher non-fuel operating expenses and higher financing costs, partially offset by higher base retail revenues and wholesale non-fuel revenues.

     Significant income statement items appropriate for discussion include the following:

	Increase (Decrease)
	First Quarter
	(in thousands)			%
Retail revenues	$	81,720			6.9
Sales for resale — non-affiliates		20,512			18.2
Sales for resale — affiliates		9,311			36.3
Other revenues		5,476			11.7
Fuel expense		125,508			40.6
Purchased power expense — non-affiliates		3,581			6.8
Purchased power expense — affiliates		(29,485	)		(13.4	)
Other operations expense		16,641			8.2
Taxes other than income taxes		6,386			10.5
Allowance for equity funds used during construction		(3,472	)		(37.5	)
Interest expense, net of amounts capitalized		9,787			19.4

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GEORGIA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Retail revenues.The chart below reflects the primary drivers of the 6.9% increase in retail revenues in the first quarter 2006 when compared to the same period in 2005. Excluding fuel cost recovery revenues, which generally do not affect net income, retail sales revenue increased by $6.3 million, or 0.8%, in the first quarter 2006, compared to the corresponding period in the prior year, primarily due to customer growth of 1.9%. In the first quarter 2006, KWH energy sales to residential and commercial customers increased by 2.8% and 4.2%, respectively, and decreased by 3.0% for industrial customers. The decrease in KWH energy sales to industrial customers was primarily the result of a 1% decrease in industrial customers resulting from the reclassification of customers from industrial to commercial when compared to the same period in 2005.

     Details of retail revenues are as follows:

	First Quarter 2006
	(in millions)			% change
Retail — prior year	$	1,185
Change in —
Base rates		—			—
Sales growth		11			0.9
Weather		(5	)		(0.4	)
Fuel cost recovery		76			6.4
Retail — current year	$	1,267			6.9

     Sales for resale — non-affiliates.Energy revenues from sales for resale to non-affiliates increased in the first quarter 2006 when compared to the same period in 2005 as a result of a 2.1% increase in the demand of KWH energy sales and $4.0 million in higher costs for sulfur dioxide emission allowances which increased the pricing for the sales for resale to non-affiliates. Energy sales do not have a significant impact on earnings since energy is usually sold at variable cost. The capacity component of these transactions remained relatively constant in the first quarter 2006 when compared to the corresponding period in 2005.

     Sales for resale — affiliates.Energy sales to affiliated companies within the Southern Company system will vary depending on demand and the availability and cost of generating resources at each company. These sales are made in accordance with the IIC, as approved by the FERC. These transactions did not have a significant impact on earnings since this energy is generally sold at marginal cost. In the first quarter 2006, revenues from sales for resale increased primarily due to a 31.8% increase in KWH sales due to the lower cost of Georgia Power’s owned generation compared to its affiliates as well as higher fuel costs.

     Other revenues. During the first quarter 2006, other revenues increased when compared with the same period in 2005 primarily due to increased transmission revenues of $4.1 million related to work performed for the other owners of the integrated transmission system in the State of Georgia and higher outdoor lighting revenues of $1.4 million due to a 1.7% increase in customers.

     Fuel expense and purchased power expense. Fuel expense and purchased power expense, together, increased $99.6 million in the first quarter 2006 when compared to 2005 due to a $126 million increase in the cost of fuel offset by a $26.4 million decrease related to fewer KWHs generated and purchased. Details of the individual components follow.

Fuel expense in the first quarter 2006 increased $126 million when compared to the same period in 2005 primarily due to an additional increase in the average cost of fuel per net kilowatt-hour generated of 22.2% due to higher coal and natural gas prices. These expenses do not have a significant impact on earnings since fuel expenses are generally offset by fuel revenues through Georgia Power’s fuel cost recovery clause. See FUTURE EARNINGS POTENTIAL — “PSC Matters — Fuel Cost Recovery” and Note (H) to the Condensed Financial Statements herein for additional information.

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GEORGIA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Purchased power from affiliates decreased in the first quarter of 2006 mainly due to a 25.3% decrease in KWH sales due to the lower cost of Georgia Power’s owned generation compared to its affiliates, partially offset by an increase of 17.9% in the average cost of purchased power per net KWH when compared to the corresponding period in 2005. Energy purchases from affiliated companies within the Southern Company system will vary depending on demand and the availability and cost of generating resources at each company. These purchases are made in accordance with the IIC, as approved by the FERC. These transactions did not have a significant impact on earnings since the energy purchases are generally offset by energy revenues through Georgia Power’s fuel cost recovery clause.

Purchased power expense — non-affiliates increased 6.8% during the first quarter 2006 due to an 11.9% increase in the average cost of purchased power per net KWH when compared to the corresponding period in 2005. These expenses do not have a significant impact on earnings since energy expenses are generally offset by energy revenues through Georgia Power’s fuel cost recovery clause.

     Other operations expense.During the first quarter 2006, other operations expense increased 8.2% when compared to the same period in 2005 primarily due to an increase of $6.4 million in employee benefit expense related to pension and salary expense due to the expensing of stock options. See Note (C) to the Condensed Financial Statements herein for additional information regarding stock option expense. Also contributing to the increase in other operations expense were increases of $2.7 million and $1.7 million in customer accounting and customer assistance expenses primarily as a result of promotional expenses related to an energy efficiency program and an increased number of customer bankruptcies, respectively, and an increase in transmission expense of $3.4 million related to load dispatching and transmission of electricity by others.

     Taxes other than income taxes.Taxes other than income taxes increased 10.5% in the first quarter 2006 as a result of higher property taxes of $4.3 million due to an increase in property values and higher municipal gross receipts taxes of $2.4 million as a result of increased sales when compared to the corresponding period in 2005.

     Allowance for equity funds used during construction.The 37.5% decrease in the allowance for equity funds used during construction in the first quarter 2006 when compared to the first quarter 2005 is attributed to completion of the McIntosh combined cycle Units 10 and 11 which were placed in service in June 2005.

     Interest expense, net of amounts capitalized. During the first quarter 2006, interest expense, net of amounts capitalized increased 19.4% when compared to the corresponding period in 2005 due to the issuance of additional senior notes in 2005 and generally higher interest rates on variable rate debt and commercial paper.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Georgia Power’s future earnings potential. The level of future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Georgia Power’s business of selling electricity. These factors include Georgia Power’s ability to maintain a stable regulatory environment that continues to allow for the recovery of all prudently incurred costs. Future earnings in the near term will depend, in part, upon growth in energy sales which is subject to a number of factors. These factors include weather, competition, new energy contracts with neighboring utilities, energy conservation practiced by customers, the price of electricity, the price elasticity of demand, and the rate of economic growth in Georgia Power’s service area. For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL of Georgia Power in Item 7 of the Form 10-K.

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GEORGIA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Environmental Matters

Compliance costs related to the Clean Air Act and other environmental regulations could affect earnings if such costs cannot be fully recovered in rates on a timely basis. For additional information, including information on certain environmental litigation, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters” of Georgia Power in Item 7 and Note 3 to the financial statements of Georgia Power under “Environmental Matters” in Item 8 of the Form 10-K.

New Source Review Reform Rules

On October 20, 2005, the EPA published a proposed rule clarifying the test for determining when an emissions increase is subject to the NSR requirements. On March 17, 2006, the U.S. Court of Appeals for the District of Columbia Circuit vacated the EPA’s proposed rule which sought to clarify the scope of the existing Routine Maintenance, Repair, and Replacement Exclusion. Because this rule was not yet in effect, the court’s ruling is not anticipated to have any impact on Georgia Power. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Actions” of Georgia Power in Item 7 and Note 3 to the financial statements of Georgia Power under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K for additional information.

Plant Wansley Environmental Litigation

On March 30, 2006, the U.S. Court of Appeals for the Eleventh Circuit ruled in favor of Georgia Power on its appeal and reversed the district court’s order regarding certain alleged opacity violations at Plant Wansley. The court of appeals remanded the case to the U.S. District Court for the Northern District of Georgia for further proceedings consistent with its decision. The ultimate outcome of this matter cannot now be determined. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — Plant Wansley Environmental Litigation” of Georgia Power in Item 7 and Note 3 to the financial statements of Georgia Power under “Environmental Matters — Plant Wansley Environmental Litigation” in Item 8 of the Form 10-K for additional information.

FERC and Georgia PSC Matters

Market-Based Rate Authority

See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Market-Based Rate Authority” of Georgia Power in Item 7 and Note 3 to the financial statements of Georgia Power under “FERC Matters — Market-Based Rate Authority” in Item 8 of the Form 10-K for information on the FERC’s April 2004 order adopting a new interim analysis for measuring generation market power and a proceeding initiated by the FERC in December 2004 to assess Southern Company’s generation dominance within its retail service territory. Georgia Power has authorization from the FERC to sell power to non-affiliates at market-based prices. Georgia Power also has 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. On February 15, 2005, Southern Company submitted additional information related to generation dominance in its retail service territory. A hearing before an administrative law judge scheduled for March 2006 has been held in abeyance to allow the parties to explore settlement. Any new market-based rate transactions in its 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. The impact of such sales through March 31, 2006 is not expected to exceed $5.1 million for Georgia Power. The refund period covers 15 months. In the event that the FERC’s default mitigation measures are ultimately applied, Georgia Power 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 the form in which the final

51

GEORGIA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

methodology for assessing generation market power and mitigation rules may be ultimately adopted and cannot be determined at this time.

     In addition, in May 2005, the FERC initiated an investigation to determine whether Southern Company satisfies the other three parts of the FERC’s market-based rate analysis: transmission market power, barriers to entry, and affiliate abuse or reciprocal dealing. The FERC established a new 15-month refund period related to this expanded investigation. Any new market-based rate transactions involving any Southern Company subsidiary will be subject to refund to the extent the FERC orders lower rates as a result of this new investigation, with the refund period beginning July 19, 2005. The impact of such sales involving Georgia Power through March 31, 2006 is not expected to exceed $11.9 million, of which $3.5 million relates to sales inside the retail service territory discussed above. The FERC also directed that this expanded proceeding be held in abeyance pending the outcome of the proceeding on the IIC discussed below.

     Georgia Power believes that there is no meritorious basis for this proceeding and is vigorously defending itself in this matter. However, the final outcome of this matter, including any remedies to be applied in the event of an adverse ruling in this proceeding, cannot now be determined.

Intercompany Interchange Contract

Also in May 2005, the FERC initiated a new proceeding to examine (1) the provisions of the IIC among Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, Southern Power, and SCS, as agent, under the terms of which the power pool of Southern Company is operated, and, in particular, the propriety of the continued inclusion of Southern Power as a party to the IIC, (2) whether any parties to the IIC have violated the FERC’s standards of conduct applicable to utility companies that are transmission providers, and (3) whether Southern Company’s code of conduct defining Southern Power as a “system company” rather than a “marketing affiliate” is just and reasonable. In connection with the formation of Southern Power, the FERC authorized Southern Power’s inclusion in the IIC in 2000. The FERC also previously approved Southern Company’s code of conduct. The FERC order directs that the administrative law judge who presided over a proceeding involving approval of PPAs between Southern Power and Georgia Power and Savannah Electric be assigned to preside over the hearing in this proceeding and that the testimony and exhibits presented in that proceeding be preserved to the extent appropriate. Effective July 19, 2005, revenues from transactions under the IIC involving any Southern Company subsidiaries will be subject to refund to the extent the FERC orders any changes to the IIC. On April 11, 2006, Southern Company, Calpine Corporation, Coral Energy, and Dalton Utilities filed a settlement offer that would resolve the proceeding. The offer is pending before the FERC and does not require any refunds. However, because the offer is pending, the final outcome of this matter cannot now be determined.See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Intercompany Interchange Contract” of Georgia Power in Item 7 and Note 3 to the financial statements of Georgia Power under “FERC Matters — Intercompany Interchange Contract” in Item 8 of the Form 10-K for additional information.

Retail Fuel Cost Recovery

On March 17, 2006, Georgia Power and Savannah Electric filed a combined request for fuel cost recovery rate changes with the Georgia PSC to be effective July 1, 2006. The requested changes will allow for the recovery of fuel costs based on an estimate of future fuel costs, as well as the collection of the existing under recovered fuel expenses. The filing also includes proposed fuel rate changes related to the previously announced proposed merger of the two companies, which is expected to be completed by July 2006.

     The request would result in an increase of about $7.22 per month, or about 8.1%, on the average Georgia Power residential customer bill and a decrease of about $8.14 a month, or about 6.4%, on the average residential

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GEORGIA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

bill for a customer in the former Savannah Electric territory. The impact for business customers would depend upon the customer’s specific rate class and usage.

     The request would increase Georgia Power’s revenues by $556 million a year, of which approximately $106 million relates to collection of the existing under recovered fuel costs. As of the end of March 2006, Savannah Electric had an under recovered fuel balance of $81 million, and Georgia Power had an under recovered fuel balance of about $784 million, including approximately $392 million related to fuel used since June 2005. The proposed fuel rates are based on an amortization period of 35 months for Georgia Power customers and 41 months for former Savannah Electric territory customers. Hearings are scheduled for May 2006 and the Georgia PSC is expected to rule on this matter in June 2006. The outcome of this matter cannot be determined at this time. See Note 3 to the financial statements of Georgia Power under “Retail Regulatory Matters — Fuel Cost Recovery” in Item 8 of the Form 10-K for additional information.

Nuclear

As part of a potential expansion of Plant Vogtle, Georgia Power and Southern Nuclear Operating Company, Inc. have notified the NRC of their intent to apply for an early site permit (ESP) this year and a combined construction and operating license (COL) in 2008. Ownership agreements have been signed with each of the existing Plant Vogtle co-owners. In February 2006, Georgia Power filed a request with the Georgia PSC to establish an accounting order that would allow Georgia Power to defer for future recovery the ESP and COL costs, of which Georgia Power’s portion is estimated to total approximately $51 million over the next four years. A hearing is scheduled for May 25, 2006, and the Georgia PSC is expected to rule on the request by the end of June 2006. The ultimate outcome of this matter cannot now be determined. At this point, no final decision has been made regarding actual construction. Any new generation resource must be certified by the Georgia PSC in a separate proceeding.

Other Matters

Georgia Power has entered into three PPAs for a total of approximately 1,000 MW annually from June 2009 through May 2024. These agreements are subject to certification by the Georgia PSC in accordance with the capacity needs identified in Georgia Power’s Integrated Resource Plan. These agreements satisfy approximately 550 MW of growth, replace an existing 450 MW agreement that expires in May 2009, and are expected to result in higher operating and maintenance expenses that will be subject to recovery through future base rates.

     On February 23, 2006, approximately 170 current and former employees of Georgia Power filed a collective action against Georgia Power in the U.S. District Court for the Northern District of Georgia, alleging that Georgia Power violated the Fair Labor Standards Act by failing to properly compensate certain employees (primarily linemen and crew leaders whose work is governed by a union collective bargaining agreement) while the employees were subject to being called back into work under on-call work rules and regulations. The plaintiffs are seeking overtime compensation for on-call time for the three-year period prior to the filing of the action, liquidated damages in an amount equal to unpaid overtime compensation they say they have been denied, declaratory and injunctive relief, and attorney’s fees and expenses of litigation. Georgia Power believes that it has complied with the provisions of the Fair Labor Standards Act and it intends to vigorously defend this action. The ultimate outcome of this matter cannot now be determined; however, an adverse outcome could result in the payment of substantial damages.

     Georgia Power is subject to certain claims and legal actions arising in the ordinary course of business. In addition, Georgia Power’s business activities are subject to extensive governmental regulation related to public health and the environment. Litigation over environmental issues and claims of various types, including

53

GEORGIA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

property damage, personal injury, and citizen enforcement of environmental requirements such as opacity and other air quality standards, 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. The ultimate outcome of such pending or potential litigation against Georgia Power cannot be predicted at this time; however, for current proceedings not specifically reported herein or in Note 3 to the financial statements of Georgia Power in Item 8 of the Form 10-K, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material adverse effect on Georgia Power’s financial statements.

     See the Notes to the Condensed Financial Statements herein for discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Georgia Power prepares its financial statements in accordance with accounting principles generally accepted in the United States. Significant accounting policies are described in Note 1 to the financial statements of Georgia Power in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on Georgia Power’s results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial
statements. Also see MANAGEMENT’S DISCUSSION AND ANALYSIS — ACCOUNTING POLICIES — “Application of Critical Accounting Policies and Estimates” of Georgia Power in Item 7 of the Form 10-K for a complete discussion of Georgia Power’s critical accounting policies and estimates related to Electric Utility Regulation, Contingent Obligations, and Unbilled Revenues.

New Accounting Standards

On January 1, 2006, Georgia Power adopted FASB Statement No. 123(R), “Share-Based Payment,” using the modified prospective method. This statement requires that compensation cost relating to share-based payment transactions be recognized in the financial statements. That cost will be measured based on the grant date fair value of the equity or liability instruments issued. Although the compensation expense required under the revised statement differs slightly, the impacts on Georgia Power’s financial statements are similar to the pro forma disclosures previously included in Note 1 to the financial statements of Georgia Power under “Stock Options” in Item 8 of the Form 10-K and in Note (C) to the Condensed Financial Statements herein. Total pre-tax compensation cost related to non-vested awards not yet recognized is expected to be approximately $4.1 million over the remaining three-year service period.

FINANCIAL CONDITION AND LIQUIDITY

Overview

Georgia Power’s financial condition remained stable at March 31, 2006. Net cash flow from operating activities decreased $28.5 million for the first three months of 2006 compared to the same period in 2005. The decrease in 2006 is primarily the result of higher fuel inventories and an increase in under recovered deferred fuel costs. Year-to-date 2006, gross property additions were $217.8 million. These additions were primarily related to the construction of transmission and distribution facilities, purchases of nuclear fuel, and purchases of equipment to comply with environmental standards. The majority of funds for these additions and other capital requirements were derived primarily from financing activities and capital contributions from Southern Company. See Georgia Power’s Condensed Statements of Cash Flows herein for further details.

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GEORGIA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Capital Requirements and Contractual Obligations

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Capital Requirements and Contractual Obligations” of Georgia Power in Item 7 of the Form 10-K for a description of Georgia Power’s capital requirements for its construction program, scheduled maturities of long-term debt, as well as related interest, lease obligations, purchase commitments, and trust funding requirements. Since December 31, 2005, Georgia Power entered into three PPAs that, subject to certification by the Georgia PSC, are expected to result in additional obligations of $55 million in 2009-2010 and $483 million thereafter. Approximately $2.8 million will be required by March 31, 2007 for redemptions and maturities of long-term debt.

Sources of Capital

Georgia Power plans to obtain the funds required for construction and other purposes from sources similar to those utilized in the past, which were primarily operating cash flows, with capital contributions from Southern Company, short-term debt, and external security issuances providing additional funds. However, the type and timing of any future financings, if needed, will depend on market conditions, regulatory approval, and other factors. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Sources of Capital” of Georgia Power in Item 7 of the Form 10-K for additional information.

     To meet short-term cash needs and contingencies, Georgia Power had at March 31, 2006 approximately $12.8 million of cash and cash equivalents and $778 million of unused credit arrangements with banks. Of these facilities, $70.4 million expire in 2006, $350 million expire in 2007, and $358 million expire in 2010. The facilities that expire in 2006 contain provisions allowing two-year term loans executable at expiration. See Note 6 to the financial statements of Georgia Power under “Bank Credit Arrangements” in Item 8 of the Form 10-K for additional information. Georgia Power expects to renew its credit facilities, as needed, prior to expiration. These unused credit arrangements provide liquidity support to Georgia Power’s obligations with respect to variable rate pollution control bonds and commercial paper. Georgia Power may also meet short-term cash needs through a Southern Company subsidiary organized to issue and sell commercial paper and extendible commercial notes at the request and for the benefit of Georgia Power and other Southern Company subsidiaries. At March 31, 2006, Georgia Power had approximately $608.8 million of commercial paper and no extendible commercial notes outstanding. Management believes that the need for working capital can be adequately met by utilizing commercial paper programs and lines of credit without maintaining large cash balances.

Credit Rating Risk

Georgia Power does not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change to BBB- or Baa3 or below. Generally, collateral may be provided for by a Southern Company guaranty, letter of credit, or cash. These contracts are primarily for physical electricity purchases and sales. At March 31, 2006, the maximum potential collateral requirements at a BBB- or Baa3 rating were approximately $8 million. The maximum potential collateral requirements at a rating below BBB- or Baa3 were approximately $247 million. Georgia Power, along with all members of the Southern Company power pool, is also party to certain derivative agreements that could require collateral and/or accelerated payment in the event of a credit rating change to below investment grade for it and/or Alabama Power. These agreements are primarily for natural gas price risk management activities. At March 31, 2006, Georgia Power’s total exposure to these types of agreements was approximately $11 million.

55

GEORGIA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Market Price Risk

Georgia Power’s market risk exposures relative to interest rate changes have not changed materially compared with the December 31, 2005 reporting period. In addition, Georgia Power is not aware of any facts or circumstances that would significantly affect such exposures in the near term.

     Due to cost-based rate regulations, Georgia Power has limited exposure to market volatility in interest rates, commodity fuel prices, and prices of electricity. To mitigate residual risks relative to movements in electricity prices, Georgia Power enters into fixed-price contracts for the purchase and sale of electricity through the wholesale electricity market. Georgia Power has also implemented a fuel hedging program at the instruction of the Georgia PSC.

     The fair value of derivative energy contracts at March 31, 2006 was as follows:

	First Quarter 2006
	Changes
	Fair Value
	(in millions)
Contracts beginning of period	$	26.6
Contracts realized or settled		(5.3)
New contracts at inception		—
Changes in valuation techniques		—
Current period changes (a)		(41.5)
Contracts at March 31, 2006	$	(20.2)

(a) Current period changes also include the changes in fair value of new contracts entered into during the period.

	Source of March 31, 2006
	Valuation Prices
	Total			Maturity
	Fair Value			Year 1			1-3 Years
				(in millions)
Actively quoted	$	(20.2	)	$	(27.5	)	$	7.3
External sources		—			—			—
Models and other methods		—			—			—
Contracts at March 31, 2006	$	(20.2	)	$	(27.5	)	$	7.3

     Unrealized gains and losses from mark to market adjustments on derivative contracts related to Georgia Power’s fuel hedging programs are recorded as regulatory assets and liabilities. Realized gains and losses from these programs are included in fuel expense and are recovered through Georgia Power’s fuel cost recovery mechanism. Of the net gains, Georgia Power is allowed to retain 25 percent in earnings. See Note 3 to the financial statements of Georgia Power under “Retail Regulatory Matters — Fuel Hedging Program” in Item 8 of the Form 10-K for additional information. Gains and losses on derivative contracts that are not designated as hedges are recognized in the statements of income as incurred. At March 31, 2006, the fair value gain/(loss) of all derivative energy contracts was reflected in the financial statements as follows:

56

GEORGIA POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

	Amounts
	(in millions)
Regulatory assets, net	$	(20.2	)
Accumulated other comprehensive income		—
Net income		—
Total fair value loss	$	(20.2	)

     Unrealized pre-tax gains and losses recognized in income were not material for any period presented.

     For additional information, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Market Price Risk” of Georgia Power in Item 7 and Notes 1 and 6 to the financial statements of Georgia Power under “Financial Instruments” in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein.

Financing Activities

Georgia Power did not issue any long-term securities during the first three months of 2006. In January 2006, all outstanding shares of the remaining issue of preferred stock were redeemed. In February 2006, Georgia Power redeemed $150 million of Series G 6.200% Senior Notes. Also during the first quarter, Georgia Power entered into two derivative transactions to reduce its exposure to interest rate risk. The transactions consisted of a hedge of an anticipated $150 million senior note issuance in 2006 and a hedge of an anticipated $225 million senior note issuance in 2007.

     In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Georgia Power plans to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

57

GULF POWER COMPANY

58

GULF POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Revenues:
Retail revenues	$	179,317		$	162,282
Sales for resale —
Non-affiliates		20,838			19,712
Affiliates		52,608			32,600
Other revenues		10,279			10,003
Total operating revenues		263,042			224,597
Operating Expenses:
Fuel		121,241			92,630
Purchased power —
Non-affiliates		4,796			5,108
Affiliates		6,990			6,012
Other operations		43,490			33,769
Maintenance		14,572			17,599
Depreciation and amortization		21,985			20,749
Taxes other than income taxes		18,889			17,501
Total operating expenses		231,963			193,368
Operating Income		31,079			31,229
Other Income and (Expense):
Interest income		781			255
Interest expense, net of amounts capitalized		(9,272	)		(8,260	)
Interest expense to affiliate trusts		(1,148	)		(1,148	)
Other income (expense), net		(550	)		192
Total other income and (expense)		(10,189	)		(8,961	)
Earnings Before Income Taxes		20,890			22,268
Income taxes		7,663			7,568
Net Income		13,227			14,700
Dividends on Preferred and Preference Stock		825			54
Net Income After Dividends on Preferred and Preference Stock	$	12,402		$	14,646

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006		2005
	(in thousands)
Net Income After Dividends on Preferred and Preference Stock	$	12,402	$	14,646
Other comprehensive income (loss):
Reclassification adjustment for amounts included in net income, net of tax of $31 and $31, respectively		50		51
COMPREHENSIVE INCOME	$	12,452	$	14,697

The accompanying notes as they relate to Gulf Power are an integral part of these condensed financial statements.

59

GULF POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Activities:
Net income	$	13,227		$	14,700
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization		23,488			22,209
Deferred income taxes		(6,462	)		(2,230	)
Pension, postretirement, and other employee benefits		1,358			1,219
Stock option expense		599			—
Tax benefit of stock options		48			534
Other, net		3,222			(3,950	)
Changes in certain current assets and liabilities —
Receivables		26,332			28,839
Fossil fuel stock		(7,852	)		(11,650	)
Materials and supplies		(153	)		464
Prepaid income taxes		295			732
Property damage cost recovery		5,116			—
Other current assets		556			4,898
Accounts payable		(3,142	)		(8,853	)
Accrued taxes		10,280			(150	)
Accrued compensation		(15,594	)		(11,504	)
Other current liabilities		5,889			5,878
Net cash provided from operating activities		57,207			41,136
Investing Activities:
Property additions		(38,277	)		(37,238	)
Cost of removal net of salvage		(945	)		(1,731	)
Construction payables		(3,747	)		(12,236	)
Other		(19	)		(10	)
Net cash used for investing activities		(42,988	)		(51,215	)
Financing Activities:
Decrease in notes payable, net		(8,184	)		—
Proceeds —
Capital contributions from parent company		21,000			—
Gross excess tax benefit of stock options		125			—
Payment of preferred and preference stock dividends		(825	)		(54	)
Payment of common stock dividends		(17,575	)		(17,100	)
Other		(602	)		(171	)
Net cash used for financing activities		(6,061	)		(17,325	)
Net Change in Cash and Cash Equivalents		8,158			(27,404	)
Cash and Cash Equivalents at Beginning of Period		3,847			64,829
Cash and Cash Equivalents at End of Period	$	12,005		$	37,425
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $7 and $317 capitalized for 2006 and 2005, respectively)	$	9,261		$	28,562
Income taxes (net of refunds)	$	2,935		$	6,720

The accompanying notes as they relate to Gulf Power are an integral part of these condensed financial statements.

60

GULF POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Assets	2006			2005
	(in thousands)
Current Assets:
Cash and cash equivalents	$	12,005		$	3,847
Receivables —
Customer accounts receivable		46,710			51,567
Unbilled revenues		32,695			39,951
Under recovered regulatory clause revenues		26,284			33,205
Other accounts and notes receivable		12,690			10,533
Affiliated companies		14,508			24,001
Accumulated provision for uncollectible accounts		(1,013	)		(1,134	)
Fossil fuel stock, at average cost		52,592			44,740
Materials and supplies, at average cost		33,129			32,976
Property damage cost recovery		29,213			28,744
Other regulatory assets		17,124			9,895
Other		12,338			19,636
Total current assets		288,275			297,961
Property, Plant, and Equipment:
In service		2,521,058			2,502,057
Less accumulated provision for depreciation		879,112			865,989
		1,641,946			1,636,068
Construction work in progress		32,794			28,177
Total property, plant, and equipment		1,674,740			1,664,245
Other Property and Investments		6,755			6,736
Deferred Charges and Other Assets:
Deferred charges related to income taxes		17,158			17,379
Prepaid pension costs		46,401			46,374
Other regulatory assets		114,892			123,258
Other		21,000			19,844
Total deferred charges and other assets		199,451			206,855
Total Assets	$	2,169,221		$	2,175,797

The accompanying notes as they relate to Gulf Power are an integral part of these condensed financial statements.

61

GULF POWER COMPANY
CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Liabilities and Stockholder's Equity	2006			2005
	(in thousands)
Current Liabilities:
Securities due within one year	$	37,075		$	37,075
Notes payable		81,280			89,465
Accounts payable —
Affiliated		30,268			36,717
Other		36,203			44,139
Customer deposits		19,692			18,834
Accrued taxes —
Income taxes		20,463			12,823
Other		11,356			11,689
Accrued interest		8,516			7,713
Accrued compensation		4,527			20,336
Other regulatory liabilities		11,669			15,671
Other		32,852			21,844
Total current liabilities		293,901			316,306
Long-term Debt		544,489			544,388
Long-term Debt Payable to Affiliated Trusts		72,166			72,166
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes		253,448			256,490
Accumulated deferred investment tax credits		16,103			16,569
Employee benefit obligations		57,620			56,235
Other cost of removal obligations		156,485			153,665
Other regulatory liabilities		24,652			26,795
Other		77,474			76,948
Total deferred credits and other liabilities		585,782			586,702
Total Liabilities		1,496,338			1,519,562
Preference Stock		53,891			53,891
Common Stockholder’s Equity:
Common stock, without par value—
Authorized - 20,000,000 shares
Outstanding - 992,717 shares		38,060			38,060
Paid-in capital		422,586			400,815
Retained earnings		161,106			166,279
Accumulated other comprehensive loss		(2,760	)		(2,810	)
Total common stockholder’s equity		618,992			602,344
Total Liabilities and Stockholder’s Equity	$	2,169,221		$	2,175,797

The accompanying notes as they relate to Gulf Power are an integral part of these condensed financial statements.

62

GULF POWER COMPANY

MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2006 vs. FIRST QUARTER 2005

OVERVIEW

Gulf Power operates as a vertically integrated utility providing electricity to retail customers within its traditional service area located in northwest Florida and to wholesale customers in the Southeast. Many factors affect the opportunities, challenges, and risks of Gulf Power’s business of selling electricity. These factors include the ability to maintain a stable regulatory environment, to achieve energy sales growth while containing costs, and to recover rising costs. These costs include those related to growing demand, increasingly stringent environmental standards, fuel prices, and storm restoration costs. Appropriately balancing environmental expenditures with customer prices will continue to challenge Gulf Power for the foreseeable future.

     Hurricanes Dennis and Katrina hit Gulf Power’s service territory in July and August 2005, respectively. As a result of these storms, as well as Hurricane Ivan in September 2004, Gulf Power has incurred significant restoration costs. Gulf Power continues to work with the Florida PSC to enable the timely recovery of these costs. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Storm Damage Cost Recovery” of Gulf Power in Item 7 of the Form 10-K and FUTURE EARNINGS POTENTIAL — “FERC and Florida PSC Matters — Storm Damage Cost Recovery” herein for additional information.

     Gulf Power continues to focus on several key performance indicators. These indicators include customer satisfaction, plant availability, system reliability, and net income. For additional information on these indicators, see MANAGEMENT’S DISCUSSION AND ANALYSIS — OVERVIEW — “Key Performance Indicators” of Gulf Power in Item 7 of the Form 10-K.

RESULTS OF OPERATIONS

Earnings

Gulf Power’s net income after dividends on preferred and preference stock for the first quarter 2006 was $12.4 million compared to $14.6 million for the corresponding period in 2005. Earnings in the first quarter 2006 decreased by $2.2 million, or 15.3%, primarily due to lower retail base revenues due to mild weather and higher non-fuel operating expenses, excluding expenses related to Hurricane Ivan, which are offset by revenues and do not affect earnings.

     Significant income statement items appropriate for discussion include the following:

	Increase (Decrease)
	First Quarter
	(in thousands)			%
Retail revenues	$	17,035			10.5
Sales for resale — non-affiliates		1,126			5.7
Sales for resale — affiliates		20,008			61.4
Fuel expense		28,611			30.9
Other operations expense		9,721			28.8
Maintenance expense		(3,027	)		(17.2	)
Interest expense, net of amounts capitalized		1,012			12.3

63

GULF POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Retail revenues.The chart below reflects the primary drivers of the 10.5% increase in retail revenues in the first quarter 2006 when compared to the corresponding period in the prior year. Excluding revenues related to fuel and other cost recovery, which do not affect net income, retail revenues decreased by $0.9 million, or 0.6%, for the first quarter 2006 as compared to the corresponding period in 2005. Retail energy sales to residential, commercial, and industrial customers decreased by 3.1%, increased by 2.8%, and decreased by 1.6%, respectively, in the first quarter 2006 as compared to the same period in 2005. Commercial sales increased primarily due to customer growth. Residential sales decreased due to unfavorable weather, while industrial sales decreased due to higher fuel prices, driving such customers to lower utilization of electricity. Other cost recovery for the first quarter 2006 includes approximately $5.5 million of revenues related to the recovery of expenses for Hurricane Ivan as approved by the Florida PSC. See Note 3 to the financial statements of Gulf Power under “Retail Regulatory Matters — Storm Damage Cost Recovery” in Item 8 of the Form 10-K and FUTURE EARNINGS POTENTIAL — “FERC and Florida PSC Matters — Storm Damage Cost Recovery” herein for additional information on storm damage cost recovery related to Hurricane Ivan.

     Details of retail revenues are as follows:

	First Quarter 2006
	(in thousands)			%
Retail — prior year	$	162,282
Change in —
Sales growth		(1,066	)		(0.7	)
Weather		152			0.1
Fuel cost recovery		8,210			5.1
Other cost recovery		9,739			6.0
Retail — current year	$	179,317			10.5	%

     Sales for resale — non-affiliates. The increase in sales for resale to non-affiliates during the first quarter 2006, as compared to the same period in 2005, is primarily the result of higher coal prices. These transactions have a minimal effect on earnings because the energy is generally sold at variable cost.

     Sales for resale — affiliates. Revenues from sales for resale to affiliates will vary depending on demand and the availability and cost of generating resources at each company within the Southern Company system. These affiliate sales are made in accordance with the IIC, as approved by the FERC. These transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost. The increase in sales for resale to affiliates in the first quarter 2006, compared to the same period in 2005, is primarily a result of increased sales of available generation at a higher unit cost due to higher fuel prices.

     Fuel expense. Fuel expense increased $28.6 million in the first quarter 2006 when compared to the same period in 2005 due to a $17.3 million increase in the cost of fuel and a $11.3 million increase related to greater total KWHs generated. In the first quarter 2006, the cost of fuel was higher than the same period in 2005 primarily due to a 29.0% increase in coal prices and a 38.3% increase in natural gas prices. Since energy expenses are generally offset by energy revenues through Gulf Power’s fuel cost recovery mechanism, these expenses do not have a material impact on net income. See FUTURE EARNINGS POTENTIAL — “FERC and Florida PSC Matters — Fuel Cost Recovery” herein for additional information.

     Other operations expense. The $9.7 million increase in other operations expense during the first quarter 2006, as compared to the same period in 2005, is primarily due to the recovery of Hurricane Ivan restoration costs as approved by the Florida PSC. Since these costs are recognized as revenues are collected, there is no impact on net income. See Note 3 to the financial statements of Gulf Power under “Retail Regulatory Matters — Storm Damage Cost Recovery” in Item 8 of the Form 10-K and FUTURE EARNINGS POTENTIAL — “FERC and Florida PSC Matters — Storm Damage Cost Recovery” herein for additional information.

64

GULF POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Maintenance expense. In the first quarter 2006, maintenance expense was $3 million lower than the same period in 2005 primarily due to a delay in scheduled maintenance performed on power generation facilities in 2006.

     Interest expense, net of amounts capitalized. In the first quarter 2006, interest expense, net of amounts capitalized, was $1 million higher than the same period in 2005 primarily due to higher interest rates on variable-rate pollution control bonds and the issuance of $60 million in senior notes in August 2005.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Gulf Power’s future earnings potential. The level of future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Gulf Power’s primary business of selling electricity. These factors include the ability of Gulf Power to maintain a stable regulatory environment that continues to allow for the recovery of all prudently incurred costs. Future earnings in the near term will depend, in part, upon growth in energy sales, which is subject to a number of factors. These factors include weather, competition, new energy contracts with neighboring utilities, energy conservation practiced by customers, the price of electricity, the price elasticity of demand, and the rate of economic growth in Gulf Power’s service area. For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL of Gulf Power in Item 7 of the Form 10-K.

Environmental Matters

Compliance costs related to the Clean Air Act and other environmental regulations could affect earnings if such costs cannot be fully recovered in rates on a timely basis. For additional information, including information on certain environmental litigation, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters” of Gulf Power in Item 7 and Note 3 to the financial statements of Gulf Power under “New Source Review Actions” and “Environmental Remediation” in Item 8 of the Form 10-K.

New Source Review Reform Rules

On October 20, 2005, the EPA published a proposed rule clarifying the test for determining when an emissions increase is subject to the NSR requirements. On March 17, 2006, the U.S. Court of Appeals for the District of Columbia Circuit vacated the EPA’s proposed rule which sought to clarify the scope of the existing Routine Maintenance, Repair, and Replacement Exclusion. Because this rule was not yet in effect, the court’s ruling is not anticipated to have any impact on Gulf Power. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Actions” of Gulf Power in Item 7 and Note 3 to the financial statements of Gulf Power under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K for additional information.

FERC and Florida PSC Matters

Market-Based Rate Authority

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “FERC Matters — Market-Based Rate Authority” of Gulf Power in Item 7 and Note 3 to the financial statements of Gulf Power under “FERC Matters — Market-Based Rate Authority” in Item 8 of the Form 10-K for information on the FERC’s April 2004 order adopting a new interim analysis for measuring generation market power and a proceeding initiated by the FERC in December 2004 to assess Southern Company’s

65

GULF POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

generation dominance within its retail service territory. Gulf Power has authorization from the FERC to sell power to non-affiliates at market-based prices. Gulf Power also has 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. On February 15, 2005, Southern Company submitted additional information related to generation dominance in its retail service territory. A hearing before an administrative law judge scheduled for March 2006 has been held in abeyance to allow the parties to explore settlement. Any new market-based rate transactions in its 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. The impact of such sales through March 31, 2006 is not expected to exceed $0.8 million for Gulf Power. The refund period covers 15 months. In the event that the FERC’s default mitigation measures are ultimately applied, Gulf Power 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 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.

     In addition, in May 2005, the FERC initiated an investigation to determine whether Southern Company satisfies the other three parts of the FERC’s market-based rate analysis: transmission market power, barriers to entry, and affiliate abuse or reciprocal dealing. The FERC established a new 15-month refund period related to this expanded investigation. Any new market-based rate transactions involving any Southern Company subsidiary will be subject to refund to the extent the FERC orders lower rates as a result of this new investigation, with the refund period beginning July 19, 2005. The impact of such sales involving Gulf Power through March 31, 2006 is not expected to exceed $2 million, of which $0.6 million relates to sales inside the retail service territory discussed above. The FERC also directed that this expanded proceeding be held in abeyance pending the outcome of the proceeding on the IIC discussed below.

     Gulf Power believes that there is no meritorious basis for this proceeding and is vigorously defending itself in this matter. However, the final outcome of this matter, including any remedies to be applied in the event of an adverse ruling in this proceeding, cannot now be determined.

Intercompany Interchange Contract

Also in May 2005, the FERC initiated a new proceeding to examine (1) the provisions of the IIC among Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, Southern Power, and SCS, as agent, under the terms of which the power pool of Southern Company is operated, and, in particular, the propriety of the continued inclusion of Southern Power as a party to the IIC, (2) whether any parties to the IIC have violated the FERC’s standards of conduct applicable to utility companies that are transmission providers, and (3) whether Southern Company’s code of conduct defining Southern Power as a “system company” rather than a “marketing affiliate” is just and reasonable. In connection with the formation of Southern Power, the FERC authorized Southern Power’s inclusion in the IIC in 2000. The FERC also previously approved Southern Company’s code of conduct. The FERC order directs that the administrative law judge who presided over a proceeding involving approval of PPAs between Southern Power and Georgia Power and Savannah Electric be assigned to preside over the hearing in this proceeding and that the testimony and exhibits presented in that proceeding be preserved to the extent appropriate. Effective July 19, 2005, revenues from transactions under the IIC involving any Southern Company subsidiaries will be subject to refund to the extent the FERC orders any changes to the IIC. On April 11, 2006, Southern Company, Calpine Corporation, Coral Energy, and Dalton Utilities filed a settlement offer that would resolve the proceeding. The offer is pending before the FERC and does not require any refunds. However, because the offer is pending, the final outcome of this matter cannot now be determined.See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Intercompany Interchange Contract” of Gulf Power in Item 7 and Note 3 to the financial statements of Gulf Power under “FERC Matters — Intercompany Interchange Contract” in Item 8 of the Form 10-K for additional information.

66

GULF POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Storm Damage Cost Recovery

In July and August 2005, Hurricanes Dennis and Katrina, respectively, hit the Gulf Coast of the United States and caused significant damage within Gulf Power’s service area. Hurricane Ivan hit the Gulf Coast of Florida and Alabama in September 2004, also causing significant damage to Gulf Power’s service area. Gulf Power maintains a reserve to cover the cost of damages from major storms to its transmission and distribution lines and the cost of uninsured damages to its generation facilities and other property. As of March 31, 2006, the deficit balance in Gulf Power’s property damage reserve account totaled approximately $41.3 million, of which approximately $3.5 million and $37.8 million, respectively, is included in the Condensed Balance Sheets herein under “Current Assets” and “Deferred Charges and Other Assets.” As of March 31, 2006, Gulf Power had recovered $26.7 million of the costs allowed for recovery related to Hurricane Ivan. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Storm Damage Cost Recovery” of Gulf Power in Item 7 and Note 3 to the financial statements of Gulf Power under “Retail Regulatory Matters — Storm Damage Cost Recovery” in Item 8 of the Form 10-K for additional information.

Fuel Cost Recovery

Gulf Power has established fuel cost recovery rates approved by the Florida PSC. In recent quarters, Gulf Power has continued to experience higher than expected fuel costs for coal and natural gas. If the projected fuel revenue over or under recovery exceeds 10 percent of the projected fuel costs for the period, Gulf Power is required to notify the Florida PSC to determine if an adjustment to the fuel cost recovery factor is necessary. Under recovered fuel costs at March 31, 2006 totaled $24.8 million, and are included in “Under Recovered Regulatory Clause Revenues” on the balance sheet. Fuel cost recovery revenues, as recorded on the financial statements, are adjusted for differences in actual recoverable costs and amounts billed in current regulated rates. Accordingly, any change in the billing factor would have no significant effect on Gulf Power’s revenues or net income, but would change cash flow.

Other Matters

Gulf Power is subject to certain claims and legal actions arising in the ordinary course of business. In addition, Gulf Power’s business activities are subject to extensive governmental regulation related to public health and the environment. Litigation over environmental issues and claims of various types, including property damage, personal injury, and citizen enforcement of environmental requirements such as opacity and other air quality standards, 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. The ultimate outcome of such pending or potential litigation against Gulf Power cannot be predicted at this time; however, for current proceedings not specifically reported herein or in Note 3 to the financial statements of Gulf Power in Item 8 of the Form 10-K, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material adverse effect on Gulf Power’s financial statements.

     See Note (B) to the Condensed Financial Statements herein for discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Gulf Power prepares its financial statements in accordance with accounting principles generally accepted in the United States. Significant accounting policies are described in Note 1 to the financial statements of Gulf Power in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

material impact on Gulf Power’s results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT’S DISCUSSION AND ANALYSIS — ACCOUNTING POLICIES — “Application of Critical Accounting Policies and Estimates” of Gulf Power in Item 7 of the Form 10-K for a complete discussion of Gulf Power’s critical accounting policies and estimates related to Electric Utility Regulation, Contingent Obligations, and Unbilled Revenues.

New Accounting Standards

On January 1, 2006, Gulf Power adopted FASB Statement No. 123(R), “Share-Based Payment,” using the modified prospective method. This statement requires that compensation cost relating to share-based payment transactions be recognized in the financial statements. That cost will be measured based on the grant date fair value of the equity or liability instruments issued. Although the compensation expense required under the revised statement differs slightly, the impacts on Gulf Power’s financial statements are similar to the pro forma disclosures previously included in Note 1 to the financial statements of Gulf Power under “Stock Options” in Item 8 of the Form 10-K and in Note (C) to the Condensed Financial Statements herein. Total pre-tax compensation cost related to non-vested awards not yet recognized is expected to be approximately $0.9 million over the remaining three-year service period.

FINANCIAL CONDITION AND LIQUIDITY

Overview

Gulf Power’s financial condition remained stable at March 31, 2006. Net cash flow from operating activities totaled $57.2 million for the first quarter 2006, compared to $41.1 million for the corresponding period in 2005. The $16.1 million increase in 2006 resulted primarily from cost recovery related to Hurricane Ivan and a decrease in payments related to storm damage costs. Gross property additions to utility plant were $28.7 million in the first quarter 2006. Funds for Gulf Power’s property additions were provided by operating activities and other financing activities. See Gulf Power’s Condensed Statements of Cash Flows herein for further details.

Capital Requirements and Contractual Obligations

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Capital Requirements and Contractual Obligations” of Gulf Power in Item 7 of the Form 10-K for a description of Gulf Power’s capital requirements for its construction program, lease obligations, preference stock dividends, purchase commitments, and trust funding requirements. Approximately $37.1 million will be required by March 31, 2007 for maturities of long-term debt.

Sources of Capital

Gulf Power plans to obtain the funds required for construction and other purposes from sources similar to those utilized in the past, which were primarily operating cash flows, with capital contributions from Southern Company, short-term debt, and external security issuances providing additional funds. However, the amount, type, and timing of any future financings, if needed, will depend upon regulatory approval, market conditions, and other factors. SeeMANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Sources of Capital” of Gulf Power in Item 7 of the Form 10-K for additional information. In addition, Gulf Power has filed a petition with the Florida PSC in response to legislation which authorized securitized financing as an alternative financing source for hurricane-related costs. If approved as proposed, the plan will allow Gulf Power to issue securitized storm-recovery bonds.

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GULF POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Gulf Power’s current liabilities exceed current assets due to the scheduled maturity of $37.1 million of long-term debt in 2006. To meet short-term cash needs and contingencies, Gulf Power has various internal and external sources of liquidity. At March 31, 2006, Gulf Power had approximately $12 million of cash and cash equivalents and $120.5 million of unused committed lines of credit with banks, all of which will expire in 2006. Gulf Power expects to renew its credit facilities, as needed, prior to expiration. See Note 6 to the financial statements of Gulf Power under “Bank Credit Arrangements” in Item 8 of the Form 10-K for additional information. These credit arrangements provide liquidity support to Gulf Power’s obligations with respect to variable rate pollution control bonds and commercial paper. A portion of these facilities may be used to fund or refinance costs related to Hurricanes Ivan, Dennis, and Katrina. In addition, Gulf Power has substantial cash flow from operating activities. Gulf Power may also meet short-term cash needs through a Southern Company subsidiary organized to issue and sell commercial paper and extendible commercial notes at the request and for the benefit of Gulf Power and other Southern Company subsidiaries. At March 31, 2006, Gulf Power had outstanding $6.3 million in commercial paper and $75 million in bank notes. There were no extendible commercial notes outstanding at March 31, 2006.

Credit Rating Risk

Gulf Power does not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change to BBB- or Baa3, or below. Generally, collateral may be provided for by a Southern Company guaranty, letter of credit, or cash. These contracts are primarily for physical electricity purchases and sales. At March 31, 2006, the maximum potential collateral requirements at a BBB- or Baa3 rating were approximately $5 million. The maximum potential collateral requirements at a rating below BBB- or Baa3 were approximately $10 million. Gulf Power, along with all members of the Southern Company power pool, is also party to certain derivative agreements that could require collateral and/or accelerated payment in the event of a credit rating change to below investment grade for Alabama Power and/or Georgia Power. These agreements are primarily for natural gas price risk management activities. At March 31, 2006, Gulf Power’s total exposure to these types of agreements was approximately $11 million.

Market Price Risk

Gulf Power’s market risk exposures relative to interest rate changes have not changed materially compared with the December 31, 2005 reporting period. In addition, Gulf Power is not aware of any facts or circumstances that would significantly affect such exposures in the near term.

     Due to cost-based rate regulation, Gulf Power has limited exposure to market volatility in interest rates, commodity fuel prices, and prices of electricity. To mitigate residual risks relative to movements in electricity prices, Gulf Power enters into fixed-price contracts for the purchase and sale of electricity through the wholesale electricity market and, to a lesser extent, into similar contracts for natural gas purchases. Gulf Power has implemented a fuel-hedging program with the approval of the Florida PSC.

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GULF POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     The fair value of derivative energy contracts at March 31, 2006 was as follows:

	First Quarter
	2006
	Changes
	Fair Value
	(in thousands)
Contracts beginning of period	$	11,526
Contracts realized or settled		(2,911	)
New contracts at inception		—
Changes in valuation techniques		—
Current period changes (a)		(11,876	)
Contracts at March 31, 2006	$	(3,261	)

(a) Current period changes also include the changes in fair value of new contracts entered into during the period.

	Source of March 31, 2006
	Valuation Prices
	Total			Maturity
	Fair Value			Year 1			1-3 Years
				(in thousands)
Actively quoted	$	(3,260	)	$	(5,959	)	$	2,699
External sources		(1	)		(1	)		—
Models and other methods		—			—			—
Contracts at March 31, 2006	$	(3,261	)	$	(5,960	)	$	2,699

     Unrealized gains and losses from mark-to-market adjustments on derivative contracts related to Gulf Power’s fuel hedging programs are recorded as regulatory assets and liabilities. Realized gains and losses from these programs are included in fuel expense and are recovered through Gulf Power’s fuel cost recovery clause. Gains and losses on derivative contracts that are not designated as hedges are recognized in the statements of income as incurred. At March 31, 2006, the fair value gain/(loss) of derivative energy contracts was reflected in the financial statements as follows:

	Amounts
	(in thousands)
Regulatory assets, net	$	(3,261	)
Accumulated other comprehensive income		—
Net income		—
Total fair value loss	$	(3,261	)

     Unrealized gains (losses) recognized in income were not material for any period presented.

     For additional information, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Market Price Risk” of Gulf Power in Item 7 and Notes 1 and 6 to the financial statements of Gulf Power under “Financial Instruments” in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein.

Financing Activities

Gulf Power did not issue or redeem any long-term securities in the first quarter of 2006. In addition to any financings that may be necessary to meet capital requirements, contractual obligations, and storm recovery, Gulf Power plans to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

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MISSISSIPPI POWER COMPANY

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MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Revenues:
Retail revenues	$	131,364		$	131,794
Sales for resale —
Non-affiliates		61,322			59,586
Affiliates		11,772			18,932
Other revenues		4,483			4,904
Total operating revenues		208,941			215,216
Operating Expenses:
Fuel		78,263			91,039
Purchased power —
Non-affiliates		4,702			5,419
Affiliates		19,036			9,604
Other operations		37,277			39,510
Maintenance		14,415			15,538
Depreciation and amortization		12,320			8,057
Taxes other than income taxes		14,200			14,145
Total operating expenses		180,213			183,312
Operating Income		28,728			31,904
Other Income and (Expense):
Interest income		49			35
Interest expense		(4,291	)		(3,526	)
Interest expense to affiliate trusts		(649	)		(649	)
Other income (expense), net		943			429
Total other income and (expense)		(3,948	)		(3,711	)
Earnings Before Income Taxes		24,780			28,193
Income taxes		9,065			10,813
Net Income		15,715			17,380
Dividends on Preferred Stock		433			433
Net Income After Dividends on Preferred Stock	$	15,282		$	16,947

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006		2005
	(in thousands)
Net Income After Dividends on Preferred Stock	$	15,282	$	16,947
Other comprehensive income (loss):
Changes in fair value of qualifying hedges, net of tax of $140 and $(172), respectively		225		(277	)
COMPREHENSIVE INCOME	$	15,507	$	16,670

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

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MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Activities:
Net income	$	15,715		$	17,380
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization		16,680			15,467
Deferred income taxes and investment tax credits, net		10,943			6,956
Plant Daniel capacity		(3,252	)		(6,281	)
Pension, postretirement, and other employee benefits		1,506			1,473
Stock option expense		743			—
Tax benefit of stock options		25			1,067
Other, net		(8,790	)		66
Changes in certain current assets and liabilities —
Receivables		54,402			22,285
Fossil fuel stock		12,561			(3,553	)
Materials and supplies		460			(132	)
Other current assets		(3,764	)		(1,378	)
Hurricane Katrina accounts payable		(36,088	)		—
Other accounts payable		(51,267	)		(4,327	)
Accrued taxes		(31,003	)		(20,795	)
Accrued compensation		(18,661	)		(15,302	)
Over recovered regulatory clause revenues		(10,797	)		(3,373	)
Other current liabilities		(6,681	)		(2,328	)
Net cash provided from (used for) operating activities		(57,268	)		7,225
Investing Activities:
Property additions		(52,798	)		(14,197	)
Cost of removal net of salvage		(12,229	)		265
Other		(10,149	)		(320	)
Net cash used for investing activities		(75,176	)		(14,252	)
Financing Activities:
Increase in notes payable, net		140,974			19,940
Proceeds — Gross excess tax benefit of stock options		9			—
Payment of preferred stock dividends		(433	)		(434	)
Payment of common stock dividends		(16,300	)		(15,500	)
Net cash provided from financing activities		124,250			4,006
Net Change in Cash and Cash Equivalents		(8,194	)		(3,021	)
Cash and Cash Equivalents at Beginning of Period		14,301			6,945
Cash and Cash Equivalents at End of Period	$	6,107		$	3,924
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest	$	7,073		$	2,765
Income taxes (net of refunds)	$	5,824		$	(11,281	)

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

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MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Assets	2006			2005
	(in thousands)
Current Assets:
Cash and cash equivalents	$	6,107		$	14,301
Receivables —
Customer accounts receivable		33,767			36,747
Unbilled revenues		19,955			20,267
Under recovered regulatory clause revenues		83,339			105,505
Other accounts and notes receivable		1,921			21,507
Insurance receivable		49,790			60,163
Affiliated companies		14,783			19,595
Accumulated provision for uncollectible accounts		(1,174	)		(2,321	)
Fossil fuel stock, at average cost		37,883			50,444
Materials and supplies, at average cost		28,218			28,678
Prepaid income taxes		50,182			42,278
Other regulatory assets		28,230			23,042
Other		15,517			25,160
Total current assets		368,518			445,366
Property, Plant, and Equipment:
In service		2,000,636			1,987,294
Less accumulated provision for depreciation		812,330			803,754
		1,188,306			1,183,540
Construction work in progress		52,951			52,225
Total property, plant, and equipment		1,241,257			1,235,765
Other Property and Investments		6,250			6,821
Deferred Charges and Other Assets:
Deferred charges related to income taxes		9,707			9,863
Prepaid pension costs		16,742			17,264
Deferred property damage		234,531			209,324
Other		59,870			56,866
Total deferred charges and other assets		320,850			293,317
Total Assets	$	1,936,875		$	1,981,269

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

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MISSISSIPPI POWER COMPANY
CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Liabilities and Stockholder’s Equity	2006			2005
	(in thousands)
Current Liabilities:
Notes payable	$	343,098		$	202,124
Accounts payable —
Affiliated		28,782			122,899
Other		61,712			89,598
Customer deposits		7,576			7,298
Accrued taxes —
Income taxes		15,038			17,736
Other		16,677			48,296
Accrued interest		3,173			3,408
Accrued compensation		5,926			24,587
Over recovered regulatory clause revenues		15,390			26,188
Plant Daniel capacity		11,171			13,008
Other		33,585			40,334
Total current liabilities		542,128			595,476
Long-term Debt		242,549			242,548
Long-term Debt Payable to Affiliated Trusts		36,082			36,082
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes		281,079			266,629
Deferred credits related to income taxes		18,493			19,003
Accumulated deferred investment tax credits		17,168			17,465
Employee benefit obligations		59,301			58,318
Other cost of removal obligations		81,703			81,284
Other regulatory liabilities		9,931			13,755
Other		54,516			56,769
Total deferred credits and other liabilities		522,191			513,223
Total Liabilities		1,342,950			1,387,329
Preferred Stock		32,780			32,780
Common Stockholder’s Equity:
Common stock, without par value —
Authorized — 1,130,000 shares
Outstanding — 1,121,000 shares		37,691			37,691
Paid-in capital		300,313			299,536
Retained earnings		226,684			227,701
Accumulated other comprehensive loss		(3,543	)		(3,768	)
Total common stockholder’s equity		561,145			561,160
Total Liabilities and Stockholder’s Equity	$	1,936,875		$	1,981,269

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

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MISSISSIPPI POWER COMPANY

MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2006 vs. FIRST QUARTER 2005

OVERVIEW

Mississippi Power operates as a vertically integrated utility providing electricity to retail customers within its traditional service area located within the State of Mississippi and to wholesale customers in the Southeast. Many factors affect the opportunities, challenges, and risks of Mississippi Power’s business of selling electricity. These factors include the ability to maintain a stable regulatory environment, to achieve energy sales growth while containing costs, and to recover costs related to growing demand and increasingly stringent environmental standards. Hurricane Katrina hit Mississippi Power’s service territory in August 2005. As a result, Mississippi Power has incurred significant restoration costs. In addition, fuel costs rose significantly during 2005 and the first quarter of 2006. Mississippi Power will continue to work with the Mississippi PSC to develop methods to enable the timely recovery of these costs.

     Mississippi Power continues to focus on several key performance indicators. In recognition that Mississippi Power’s long-term financial success is dependent upon how well it satisfies its customers’ needs, Mississippi Power’s retail base rate mechanism, PEP, includes performance indicators that directly tie customer service indicators to Mississippi Power’s allowed return. In addition to the PEP performance indicators, Mississippi Power focuses on other performance measures, including broader measures of customer satisfaction, plant availability, system reliability, and net income. For additional information on these indicators, see MANAGEMENT’S DISCUSSION AND ANALYSIS — OVERVIEW — “Key Performance Indicators” of Mississippi Power in Item 7 of the Form 10-K.

RESULTS OF OPERATIONS

Earnings

Mississippi Power’s net income after dividends on preferred stock for the first quarter 2006 was $15.3 million compared to $16.9 million for the corresponding period of 2005. Earnings in the first quarter 2006 decreased by $1.6 million, or 9.8%, compared to the same period of 2005 primarily as a result of a $4.1 million decrease in territorial base revenues and a $4.3 million increase in depreciation and amortization expense, which was partially offset by an increase of $3 million in non-territorial energy revenues, and a decrease of $3.4 million in non-fuel operations and maintenance expenses.

     Significant income statement items appropriate for discussion include the following:

	Increase (Decrease)
	First Quarter
	(in thousands)			%
Retail revenues	$	(430	)		(0.3	)
Sales for resale — non-affiliates		1,736			2.9
Sales for resale — affiliates		(7,160	)		(37.8	)
Fuel expense		(12,776	)		(14.0	)
Purchased power expense — non-affiliates		(717	)		(13.2	)
Purchased power expense — affiliates		9,432			98.2
Other operations expense		(2,233	)		(5.7	)
Maintenance expense		(1,123	)		(7.2	)
Depreciation and amortization		4,263			52.9
Interest expense		765			21.7
Other income (expense), net		514			119.8
Income taxes		(1,748	)		(16.2	)

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     Retail revenues.The chart below reflects the primary drivers of the 0.3% decrease in retail revenues in the first quarter 2006 compared to the same period in the prior year. Excluding revenues related to fuel and other cost recovery, which do not affect net income, retail revenues decreased as a result of Hurricane Katrina. In the first quarter 2006, KWH sales to residential, commercial, and industrial customers were down 15.9%, 14.7%, and 7.7%, respectively, when compared to the corresponding period in 2005 due to Hurricane Katrina and the loss of approximately 18,000 customers.

Details of retail revenues are as follows:

	First Quarter
	2006
	(in thousands)			% change
Retail — prior year	$	131,794
Change in —
Base rates		1,710			1.3
Sales growth and weather		(5,575	)		(4.3	)
Fuel cost recovery		3,612			2.8
Other cost recovery		(177	)		(0.1	)
Retail — current year	$	131,364			(0.3	)%

     Sales for resale—non-affiliates and Purchased power expense — non-affiliates.The $1.7 million increase in sales for resale to non-affiliates costs in the first quarter 2006 as compared to the same period in 2005 was primarily the result of higher energy prices due to an increase in fuel prices. The decrease in purchased power expense from non-affiliates in the first quarter 2006 as compared to the same period in 2005 is primarily due to lower prices for opportunity purchases from non-affiliates.

     Sales for resale—affiliates and Purchased power expense—affiliates. Revenues from sales for resale to affiliates, as well as purchases of energy from affiliates, will vary depending on demand and the availability and cost of generating resources at each company within the Southern Company system. These affiliate sales and purchases are made in accordance with the IIC, as approved by the FERC. These transactions do not have a significant impact on earnings since the energy is generally sold at marginal cost and energy purchases are generally offset by energy revenues through Mississippi Power’s retail and wholesale fuel cost recovery clauses. The 37.8% decrease in sales for resale to affiliates in the first quarter 2006 as compared to the same period in 2005 is primarily the result of a 22% decrease in generation. The 98.2% increase in purchased power from affiliates in the first quarter 2006 as compared to the same period in 2005 is also due to generation decreasing by 22% while demand decreased 9%. More power (volume) is purchased to meet the gap between generation and demand. IIC rates for purchased power were higher in the first quarter 2006 when compared to the same period in 2005 due to increased fuel prices.

     Fuel expense.The first quarter 2006 decrease of $12.8 million in fuel expense when compared to the same period in 2005 is primarily due to $20.4 million decrease related to reduced generation offset by an $7.6 million increase in the cost of fuel.

     Other operations expense.The decrease in other operations expense for the first quarter 2006 as compared to the same period in 2005 results from a $3 million insurance recovery for labor expense associated with Hurricane Katrina.

     Maintenance expense.The first quarter 2006 decrease in maintenance expense when compared to the same period in 2005 resulted from decreased expenses for the combined cycle long term service agreement due to reduced operating hours as a result of the higher cost of gas. The operating hours for the first quarter of 2006

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

were 1,988 compared to 4,252 in the first quarter of 2005, a 53% decrease which reduced maintenance expense by approximately $1.1 million.

     Depreciation and amortization.The first quarter 2006 increase of $4.3 million in depreciation and amortization expense when compared to the same period in 2005 is primarily due to the decrease in the credit amortization of the regulatory liability related to additional Plant Daniel capacity and to the new depreciation rates approved by the Mississippi PSC and effective January 1, 2006. See Note 3 to the financial statements of Mississippi Power under “Retail Regulatory Matters” in Item 8 of the Form 10-K for additional information.

     Interest expense.The 21.7% increase in interest expense for the first quarter 2006 as compared to the same period in 2005 is due to higher interest rates.

     Other income (expense), net.The first quarter 2006 increase in other income (expense), net when compared to the same period in 2005 is the result of the increase in interest income related to the recovery mechanism for fuel hedging and energy cost hedging, and income associated with customer projects.

     Income taxes.The $1.7 million decrease in income taxes for the first quarter 2006 as compared to the same period in 2005 is primarily related to the reductions in pre-tax income.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Mississippi Power’s future earnings potential. The level of future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Mississippi Power’s primary business of selling electricity. These factors include the ability of Mississippi Power to maintain a stable regulatory environment that continues to allow for the recovery of all prudently incurred costs. Future earnings in the near term will depend, in part, upon growth in energy sales, which is subject to a number of factors. These factors include weather, competition, new energy contracts with neighboring utilities, energy conservation practiced by customers, the price of electricity, the price elasticity of demand, and the rate of economic growth in Mississippi Power’s service area in the aftermath of Hurricane Katrina. For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL of Mississippi Power in Item 7 of the Form 10-K.

Environmental Matters

Compliance costs related to the Clean Air Act and other environmental regulations could affect earnings if such costs cannot be fully recovered in rates on a timely basis. For additional information, including information on certain environmental litigation, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters” of Mississippi Power in Item 7 and Note 3 to the financial statements of Mississippi Power under “Environmental Matters” in Item 8 of the Form 10-K.

New Source Review Reform Rules

On October 20, 2005, the EPA published a proposed rule clarifying the test for determining when an emissions increase is subject to the NSR requirements. On March 17, 2006, the U.S. Court of Appeals for the District of Columbia Circuit vacated the EPA’s proposed rule which sought to clarify the scope of the existing Routine Maintenance, Repair, and Replacement Exclusion. Because this rule was not yet in effect, the court’s ruling is not anticipated to have any impact on Mississippi Power. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Actions”

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of Mississippi Power in Item 7 and Note 3 to the financial statements of Mississippi Power under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K for additional information.

FERC and Mississippi PSC Matters

Market-Based Rate Authority

See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Market-Based Rate Authority” of Mississippi Power in Item 7 and Note 3 to the financial statements of Mississippi Power under “FERC Matters —Market-Based Rate Authority” in Item 8 of the Form 10-K for information on the FERC’s April 2004 order adopting a new interim analysis for measuring generation market power and a proceeding initiated by the FERC in December 2004 to assess Southern Company’s generation dominance within its retail service territory. Mississippi Power has authorization from the FERC to sell power to non-affiliates at market-based prices. Mississippi Power also has 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. On February 15, 2005, Southern Company submitted additional information related to generation dominance in its retail service territory. A hearing before an administrative law judge scheduled for March 2006 has been held in abeyance to allow the parties to explore settlement. Any new market-based rate transactions in its 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. The impact of such sales through March 31, 2006 is not expected to exceed $8.3 million for Mississippi Power. The refund period covers 15 months. In the event that the FERC’s default mitigation measures are ultimately applied, Mississippi Power 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 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.

     In addition, in May 2005, the FERC initiated an investigation to determine whether Southern Company satisfies the other three parts of the FERC’s market-based rate analysis: transmission market power, barriers to entry, and affiliate abuse or reciprocal dealing. The FERC established a new 15-month refund period related to this expanded investigation. Any new market-based rate transactions involving any Southern Company subsidiary will be subject to refund to the extent the FERC orders lower rates as a result of this new investigation, with the refund period beginning July 19, 2005. The impact of such sales involving Mississippi Power through March 31, 2006 is not expected to exceed $10.5 million, of which $7.1 million relates to sales inside the retail service territory discussed above. The FERC also directed that this expanded proceeding be held in abeyance pending the outcome of the proceeding on the IIC discussed below.

     Mississippi Power believes that there is no meritorious basis for this proceeding and is vigorously defending itself in this matter. However, the final outcome of this matter, including any remedies to be applied in the event of an adverse ruling in this proceeding, cannot now be determined.

Intercompany Interchange Contract

Also in May 2005, the FERC initiated a new proceeding to examine (1) the provisions of the IIC among Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, Southern Power, and SCS, as agent, under the terms of which the power pool of Southern Company is operated, and, in particular, the propriety of the continued inclusion of Southern Power as a party to the IIC, (2) whether any parties to the IIC have violated the FERC’s standards of conduct applicable to utility companies that are transmission providers, and (3) whether Southern Company’s code of conduct defining Southern Power as a “system company” rather than a “marketing affiliate” is just and reasonable. In connection with the formation of Southern Power, the FERC authorized Southern Power’s inclusion in the IIC in 2000. The FERC also

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previously approved Southern Company’s code of conduct. The FERC order directs that the administrative law judge who presided over a proceeding involving approval of PPAs between Southern Power and Georgia Power and Savannah Electric be assigned to preside over the hearing in this proceeding and that the testimony and exhibits presented in that proceeding be preserved to the extent appropriate. Effective July 19, 2005, revenues from transactions under the IIC involving any Southern Company subsidiaries will be subject to refund to the extent the FERC orders any changes to the IIC. On April 11, 2006, Southern Company, Calpine Corporation, Coral Energy, and Dalton Utilities filed a settlement offer that would resolve the proceeding. The offer is pending before the FERC and does not require any refunds. However, because the offer is pending, the final outcome of this matter cannot now be determined.See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Intercompany Interchange Contract” of Mississippi Power in Item 7 and Note 3 to the financial statements of Mississippi Power under “FERC Matters — Intercompany Interchange Contract” in Item 8 of the Form 10-K for additional information.

Storm Damage Cost Recovery

In August 2005, Hurricane Katrina hit the Gulf Coast of the United States and caused significant damage within Mississippi Power’s service area. Mississippi Power maintains a reserve to cover the cost of damages from major storms to its transmission and distribution lines and the cost of uninsured damages to its generation facilities and other property. As of March 31, 2006, the deficit balance in Mississippi Power’s storm damage reserve account totaled approximately $234.5 million, which is included in the Condensed Balance Sheets herein under “Deferred property damage.” See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Storm Damage Cost Recovery” of Mississippi Power in Item 7 and Note 3 to the financial statements of Mississippi Power under “Retail Regulatory Matters — Storm Damage Cost Recovery” in Item 8 of the Form 10-K for additional information.

In October 2005, the Mississippi PSC issued an Interim Accounting Order requiring Mississippi Power to recognize a regulatory asset in an amount equal to the retail portion of the recorded Hurricane Katrina restoration costs, including both operation and maintenance expenditures and capital additions. In December 2005, Mississippi Power filed with the Mississippi PSC a detailed review of all Hurricane Katrina restoration costs as required in the Interim Accounting Order. Mississippi Power is currently working with the Mississippi PSC to establish a method to recover all such prudently incurred costs, while minimizing the impact on Mississippi Power’s customers. The Department of Defense emergency supplemental appropriations bill, enacted in December 2005 to address hurricanes in the Gulf of Mexico, provides $11 billion in disaster relief for the States of Mississippi, Louisiana, and Alabama. In the State of Mississippi, $300 million in grant assistance in the form of Community Development Block Grants (CDBGs) is expected to be designated for utilities within the state. Mississippi Power plans to apply for these CDBGs to offset the cost of storm recovery. Mississippi Power is also considering securitization of remaining unrecovered costs as provided for under legislation passed in Mississippi in the first quarter of 2006. The final outcome of these matters cannot now be determined.

Retail Regulatory Matters

Also in December 2005, Mississippi Power submitted its annual PEP filing to the Mississippi PSC. Ordinarily, PEP limits annual rate increases to 4 percent; however, Mississippi Power requested that the Mississippi PSC approve a temporary change to allow it to exceed this cap as a result of the ongoing effects of Hurricane Katrina. Mississippi Power had requested a 5.05%, or $32 million, retail base rate increase to become effective in April 2006. Hearings were held in March 2006 and the full increase was approved by the Mississippi PSC on March 13, 2006.

     On February 7, 2006, Mississippi Power filed with the Mississippi PSC its annual ECO Plan evaluation. Mississippi Power requested a 12 cent per 1,000 KWH reduction for retail customers. This decrease would represent a reduction of approximately $1.3 million per year in annual revenues for Mississippi Power.

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Hearings were held on April 4, 2006. The Mississippi PSC unanimously approved the decrease at the hearings and issued an order confirming approval on April 21, 2006.

Fuel Cost Recovery

Mississippi Power has established a fuel cost recovery factor that is approved by the Mississippi PSC. In 2005, Mississippi Power experienced higher than expected fuel costs for coal and gas, which led to an increase in the under-recovered fuel costs. Mississippi Power is required to file for an adjustment to the fuel cost recovery factor annually; the last such filing was made in November 2005, with the new rate becoming effective in January 2006. At March 31, 2006, the under recovered balance of fuel was $67.9 million. Mississippi Power’s operating revenues are adjusted for differences in actual recoverable fuel cost and amounts billed in accordance with the currently approved cost recovery rate. Accordingly, changes to the billing factor will have no significant effect on Mississippi Power’s revenues or net income but will change cash flow.

Other Matters

Mississippi Power is subject to certain claims and legal actions arising in the ordinary course of business. In addition, Mississippi Power’s business activities are subject to extensive governmental regulation related to public health and the environment. Litigation over environmental issues and claims of various types, including property damage, personal injury, and citizen enforcement of environmental requirements such as opacity and other air quality standards, 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. The ultimate outcome of such pending or potential litigation against Mississippi Power cannot be predicted at this time; however, for current proceedings not specifically reported herein or in Note 3 to the financial statements of Mississippi Power in Item 8 of the Form 10-K, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material adverse effect on Mississippi Power’s financial statements.

     See the Notes to the Condensed Financial Statements herein for discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Mississippi Power prepares its financial statements in accordance with accounting principles generally accepted in the United States. Significant accounting policies are described in Note 1 to the financial statements of Mississippi Power in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on Mississippi Power’s results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT’S DISCUSSION AND ANALYSIS — ACCOUNTING POLICIES — “Application of Critical Accounting Policies and Estimates” of Mississippi Power in Item 7 of the Form 10-K for a complete discussion of Mississippi Power’s critical accounting policies and estimates related to Electric Utility Regulation, Contingent Obligations, Unbilled Revenues, and Plant Daniel Operating Lease.

New Accounting Standards

On January 1, 2006, Mississippi Power adopted FASB Statement No. 123(R), “Share-Based Payment,” using the modified prospective method. This statement requires that compensation cost relating to share-based payment transactions be recognized in the financial statements. That cost will be measured based on the grant date fair value of the equity or liability instruments issued. Although the compensation expense required under

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the revised statement differs slightly, the impacts on Mississippi Power’s financial statements are similar to the pro forma disclosures previously included in Note 1 to the financial statements of Mississippi Power under “Stock Options” in Item 8 of the Form 10-K and in Note (C) to the Condensed Financial Statements herein. Total pre-tax compensation cost related to non-vested awards not yet recognized is expected to be approximately $0.7 million over the remaining three-year service period.

FINANCIAL CONDITION AND LIQUIDITY

Overview

Mississippi Power’s financial condition remained stable at March 31, 2006. Net cash provided from (used for) operating activities totaled $(57.3) million for the first quarter 2006, compared to net cash flow provided from operating activities of $7.2 million for the same period in 2005. The $64.5 million decrease in 2006 resulted primarily from cash requirements associated with Hurricane Katrina restoration.

Capital Requirements and Contractual Obligations

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Capital Requirements and Contractual Obligations” of Mississippi Power in Item 7 of the Form 10-K for a description of Mississippi Power’s capital requirements for its construction program, lease obligations, purchase commitments, preferred stock dividends, and trust funding requirements. Mississippi Power has no maturities or redemptions of long-term debt required by March 31, 2007.

Sources of Capital

Mississippi Power plans to obtain the funds required for construction, continued storm damage restoration, and other purposes from sources similar to those used in the past, including operating cash flows, capital contributions from Southern Company, short-term debt, and external security issuances. In addition, Mississippi Power is considering other financing options, including securitization, for storm damage recovery costs. The amount, type, and timing of any future financings, if needed, will depend upon maintenance of adequate earnings, regulatory approval, prevailing market conditions, and other factors. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Sources of Capital” of Mississippi Power in Item 7 of the Form 10-K for additional information.

     At March 31, 2006, Mississippi Power’s current liabilities exceeded current assets primarily as a result of obligations incurred as a result of Hurricane Katrina, as well as the continued use of short-term debt as a funding source to meet cash needs, which can fluctuate significantly due to the seasonality of the business. To meet short-term cash needs and contingencies, Mississippi Power had at March 31, 2006 approximately $6.1 million of cash and cash equivalents and $275.5 million of unused committed credit arrangements with banks, $100.5 million of which expire in 2006 and $175 million of which expire in 2008. See Note 6 to the financial statements of Mississippi Power under “Bank Credit Arrangements” in Item 8 of the Form 10-K for additional information. Approximately $38.0 million of these credit arrangements contain provisions allowing two-year term loans executable at expiration and $15 million contain provisions allowing one-year term loans executable at expiration. Mississippi Power expects to renew its credit facilities, as needed, prior to expiration. The credit arrangements provide liquidity support to Mississippi Power’s obligations with respect to variable rate pollution control bonds and commercial paper. A portion of these facilities may be used to fund or refinance costs related to Hurricane Katrina. At March 31, 2006, Mississippi Power had $163.2 million in commercial paper, $150 million in bank notes and $29.8 million in extendible commercial notes outstanding. Management believes that the need for working capital can be adequately met by utilizing commercial paper programs and lines of credit without maintaining large cash balances.

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Off-Balance Sheet Financing Arrangements

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Off-Balance Sheet Financing Arrangements” of Mississippi Power in Item 7 and Note 7 to the financial statements of Mississippi Power under “Operating Leases” in Item 8 of the Form 10-K for information related to Mississippi Power’s lease of a combined cycle generating facility at Plant Daniel.

Credit Rating Risk

Mississippi Power does not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. Mississippi Power, along with all members of the Southern Company power pool, is also party to certain derivative agreements that could require collateral and/or accelerated payment in the event of a credit rating change to below investment grade for Alabama Power and/or Georgia Power. These agreements are primarily for natural gas price risk management activities. At March 31, 2006, Mississippi Power’s total exposure to these types of agreements was approximately $11 million.

Market Price Risk

Mississippi Power’s market risk exposures relative to interest rate changes have not changed materially compared with the December 31, 2005 reporting period. However, as a result of storm damage from Hurricane Katrina, Mississippi Power expects to maintain the increase in short-term indebtedness in the coming months while issues relating to storm cost recovery are resolved, which could significantly increase its exposure to interest rate risk. Mississippi Power will manage this increased exposure through a number of means, including interest rate hedges, where appropriate.

     Due to cost-based rate regulation, Mississippi Power has limited exposure to market volatility in interest rates, commodity fuel prices, and prices of electricity. To mitigate residual risks relative to movements in electricity prices, Mississippi Power enters into fixed-price contracts for the purchase and sale of electricity through the wholesale electricity market. Mississippi Power has also implemented retail fuel hedging programs at the instruction of the Mississippi PSC and wholesale fuel hedging programs under agreements with wholesale customers.

     The fair value of derivative, fuel, and energy contracts at March 31, 2006 was as follows:

	First Quarter
	2006
	Changes
	Fair Value
	(in thousands)
Contracts beginning of period	$	27,106
Contracts realized or settled		(3,030	)
New contracts at inception		—
Changes in valuation techniques		—
Current period changes (a)		(14,184	)
Contracts at March 31, 2006	$	9,892

(a) Current period changes also include the changes in fair value of new contracts entered into during the period.

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	Source of March 31, 2006
	Valuation Prices
	Total		Maturity
	Fair Value		Year 1		1-3 Years
	(in thousands)
Actively quoted	$	9,811	$	4,657	$	5,154
External sources		81		81		—
Models and other methods		—		—		—
Contracts at March 31, 2006	$	9,892	$	4,738	$	5,154

     Unrealized gains and losses from mark-to-market adjustments on derivative contracts related to Mississippi Power’s fuel hedging programs are recorded as regulatory assets and liabilities. Realized gains and losses from these programs are included in fuel expense and are recovered through Mississippi Power’s energy cost management clause. In addition, any unrealized gains and losses on energy-related derivatives used to hedge anticipated purchases and sales are deferred in other comprehensive income. Gains and losses on forward contracts for the sale of electricity that do not represent hedges are recognized in the statements of income as incurred. These amounts were not material in any period presented. At March 31, 2006, the fair value gain/(loss) of derivative energy contracts was reflected in the financial statements as follows:

	Amounts
	(in thousands)
Regulatory liabilities, net	$	9,869
Accumulated other comprehensive income		23
Net income		-
Total fair value gain	$	9,892

     For additional information, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Market Price Risk” of Mississippi Power in Item 7 and Notes 1 and 6 to the financial statements of Mississippi Power under “Financial Instruments” in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein.

Financing Activities

Mississippi Power did not issue or redeem any long-term securities in the first quarter of 2006. In addition to any financings that may be necessary to meet capital requirements, contractual obligations, and storm restoration costs, Mississippi Power plans to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

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POWER COMPANY

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SAVANNAH ELECTRIC AND POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Revenues:
Retail revenues	$	91,566		$	85,004
Sales for resale —
Non-affiliates		1,294			458
Affiliates		2,261			2,061
Other revenues		1,853			1,065
Total operating revenues		96,974			88,588
Operating Expenses:
Fuel		25,950			13,122
Purchased power —
Non-affiliates		2,242			1,886
Affiliates		27,357			36,279
Other operations		16,869			14,324
Maintenance		9,251			9,886
Depreciation and amortization		5,967			5,348
Taxes other than income taxes		4,111			3,799
Total operating expenses		91,747			84,644
Operating Income		5,227			3,944
Other Income and (Expense):
Interest income		9			17
Interest expense, net of amounts capitalized		(4,170	)		(3,223	)
Other income (expense), net		(142	)		1,106
Total other income and (expense)		(4,303	)		(2,100	)
Earnings Before Income Taxes		924			1,844
Income taxes		(44	)		149
Net Income		968			1,695
Dividends on Preferred Stock		675			675
Net Income After Dividends on Preferred Stock	$	293		$	1,020

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006		2005
	(in thousands)
Net Income After Dividends on Preferred Stock	$	293	$	1,020
Other comprehensive income (loss):
Changes in fair value of qualifying hedges, net of tax of $381 and $450, respectively		599		713
Reclassification adjustment for amounts included in net income, net of tax of $3 and $3, respectively		4		4
COMPREHENSIVE INCOME	$	896	$	1,737

The accompanying notes as they relate to Savannah Electric are an integral part of these condensed financial statements.

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CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Activities:
Net income	$	968		$	1,695
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization		6,474			5,804
Deferred income taxes and investment tax credits, net		1,778			6,606
Allowance for equity funds used during construction		(196	)		(1,194	)
Pension, postretirement, and other employee benefits		1,387			1,379
Stock option expense		289			—
Tax benefit of stock options		10			574
Other, net		(112	)		3,283
Changes in certain current assets and liabilities —
Receivables		5,013			(6,154	)
Fossil fuel stock		(3,438	)		(1,587	)
Materials and supplies		1,107			981
Other current assets		1,339			(7,365	)
Accounts payable		(13,924	)		(2,850	)
Accrued taxes		1,297			(2,476	)
Accrued compensation		(4,242	)		(3,537	)
Other current liabilities		1,964			2,041
Net cash used for operating activities		(286	)		(2,800	)
Investing Activities:
Property additions		(9,381	)		(14,179	)
Other		(2,205	)		(1,438	)
Net cash used for investing activities		(11,586	)		(15,617	)
Financing Activities:
Increase (decrease) in notes payable, net		(7,190	)		19,546
Proceeds —
Capital contributions from parent company		30,000			—
Gross excess tax benefit of stock options		22			—
Payment of preferred stock dividends		(1,350	)		(675	)
Payment of common stock dividends		(6,875	)		(6,675	)
Other		(47	)		(6	)
Net cash provided from financing activities		14,560			12,190
Net Change in Cash and Cash Equivalents		2,688			(6,227	)
Cash and Cash Equivalents at Beginning of Period		502			8,862
Cash and Cash Equivalents at End of Period	$	3,190		$	2,635
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $93 and $595 capitalized for 2006 and 2005, respectively)	$	2,591		$	1,338
Income taxes (net of refunds)	$	(3,985	)	$	(384	)

The accompanying notes as they relate to Savannah Electric are an integral part of these condensed financial statements.

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SAVANNAH ELECTRIC AND POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Assets	2006			2005
	(in thousands)
Current Assets:
Cash and cash equivalents	$	3,190		$	502
Receivables —
Customer accounts receivable		26,262			29,116
Unbilled revenues		5,814			6,651
Under recovered regulatory clause revenues		38,068			28,990
Other accounts and notes receivable		1,194			2,055
Affiliated companies		1,744			5,449
Accumulated provision for uncollectible accounts		(701	)		(916	)
Fossil fuel stock, at average cost		19,454			16,015
Materials and supplies, at average cost		10,669			11,776
Prepaid income taxes		17,046			22,629
Assets from risk management activities		4,973			8,045
Other		6,545			2,824
Total current assets		134,258			133,136
Property, Plant, and Equipment:
In service		1,041,581			1,033,256
Less accumulated provision for depreciation		401,836			396,987
		639,745			636,269
Construction work in progress		21,793			21,315
Total property, plant, and equipment		661,538			657,584
Other Property and Investments		4,297			4,279
Deferred Charges and Other Assets:
Deferred charges related to income taxes		11,406			11,455
Cash surrender value of life insurance for deferred compensation plans		27,347			27,030
Deferred under recovered regulatory clause revenues		42,854			48,689
Other regulatory assets		19,808			20,191
Other		9,413			10,437
Total deferred charges and other assets		110,828			117,802
Total Assets	$	910,921		$	912,801

The accompanying notes as they relate to Savannah Electric are an integral part of these condensed financial statements.

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SAVANNAH ELECTRIC AND POWER COMPANY
CONDENSED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Liabilities and Stockholder’s Equity	2006			2005
	(in thousands)
Current Liabilities:
Securities due within one year	$	20,992		$	21,003
Notes payable		51,580			58,771
Accounts payable —
Affiliated		16,981			29,840
Other		16,424			19,355
Customer deposits		7,245			7,068
Accrued taxes other than income taxes		3,207			1,909
Accrued interest		4,514			3,223
Accrued compensation		1,710			5,952
Other		13,268			15,020
Total current liabilities		135,921			162,141
Long-term Debt		216,791			217,033
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes		118,303			119,424
Deferred credits related to income taxes		7,760			7,978
Accumulated deferred investment tax credits		7,132			7,298
Employee benefit obligations		56,660			54,661
Other cost of removal obligations		40,637			40,575
Other regulatory liabilities		11,692			12,107
Other		10,237			10,127
Total deferred credits and other liabilities		252,421			252,170
Total Liabilities		605,133			631,344
Preferred Stock		43,899			43,909
Common Stockholder’s Equity:
Common stock, par value $5 per share —
Authorized - 16,000,000 shares
Outstanding - 10,844,635 shares		54,223			54,223
Paid-in capital		104,848			74,527
Retained earnings		104,356			110,939
Accumulated other comprehensive loss		(1,538	)		(2,141	)
Total common stockholder’s equity		261,889			237,548
Total Liabilities and Stockholder’s Equity	$	910,921		$	912,801

The accompanying notes as they relate to Savannah Electric are an integral part of these condensed financial statements.

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MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2006 vs. FIRST QUARTER 2005

OVERVIEW

Savannah Electric operates as a vertically integrated utility providing electricity to retail customers within its traditional service area of southeastern Georgia. Many factors affect the opportunities, challenges, and risks of Savannah Electric’s business of selling electricity. These factors include the ability to maintain a stable regulatory environment, to achieve energy sales growth while containing costs, and to recover costs related to growing demand and increasingly stringent environmental standards. In addition, fuel costs rose significantly during 2005 and the first quarter of 2006. Savannah Electric will continue to work with the Georgia PSC to enable the timely recovery of these costs.

     On December 13, 2005, Savannah Electric entered into a merger agreement with Georgia Power under which Savannah Electric will merge into Georgia Power, with Georgia Power continuing as the surviving corporation (the Merger), subject to receipt of all required approvals. For additional information, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “PSC Matters — Merger” of Savannah Electric in Item 7 and Note 3 to the financial statements of Savannah Electric under “Retail Regulatory Matters — Merger” in Item 8 of the Form 10-K.

     Savannah Electric continues to focus on several key performance indicators. These indicators include customer satisfaction, plant availability, system reliability, and net income. For additional information on these indicators, see MANAGEMENT’S DISCUSSION AND ANALYSIS — OVERVIEW — “Key Performance Indicators” of Savannah Electric in Item 7 of the Form 10-K.

RESULTS OF OPERATIONS

Earnings

Savannah Electric’s net income after dividends on preferred stock for the first quarter 2006 was $0.3 million compared to $1.0 million for the corresponding period of 2005. The $0.7 million decrease in the first quarter 2006 from the corresponding period in 2005 was primarily due to higher operating expenses and interest expense as well as a decrease in other income, net. These decreases were offset partially by higher operating revenues as a result of the base rate increase in June 2005. See Note 3 to the financial statements of Savannah Electric under “Retail Regulatory Matters — Rate Plans” in Item 8 of the Form 10-K for further information on the rate increase.

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     Significant income statement items appropriate for discussion include the following:

	Increase (Decrease)
	First Quarter
	(in thousands)			%
Retail revenues	$	6,562			7.7
Sales for resale — non-affiliates		836			182.5
Sales for resale — affiliates		200			9.7
Other revenues		788			74.0
Fuel expense		12,828			97.8
Purchased power expense — non-affiliates		356			18.9
Purchased power expense — affiliates		(8,922	)		(24.6	)
Other operations expense		2,545			17.8
Maintenance expense		(635	)		(6.4	)
Depreciation and amortization expense		619			11.6
Taxes other than income taxes		312			8.2
Interest expense, net of amounts capitalized		947			29.4
Other income (expense), net		(1,248	)		(112.8	)

     Retail revenues. The chart below reflects the primary drivers of the 7.7% first quarter 2006 increase in retail revenues, compared to the same period in the prior year. Excluding fuel cost recovery revenues, which do not affect net income, retail revenue increased by $2.5 million, or 6.3%, in the first quarter 2006 when compared to the corresponding period in 2005. For the first quarter 2006, this revenue increase is primarily related to the three-year retail rate plan approved by the Georgia PSC for the period ending May 31, 2008 and effective in June 2005 (the 2005 Retail Rate Plan). See FUTURE EARNINGS POTENTIAL — “PSC Matters — Rate Filing” in Item 7 of the Form 10-K.

     Details of retail revenues are as follows:

	First Quarter
	2006
	(in thousands)			% change
Retail — prior year	$	85,004
Change in —
Base rates		2,480		2.9
Sales growth		20		—
Weather		(20	)	—
Fuel cost recovery		4,082		4.8
Retail — current year	$	91,566		7.7	%

     Sales for resale-non-affiliates.In the first quarter 2006, revenues from sales for resale to non-affiliates increased $0.8 million when compared to the same period in the prior year, primarily due to an increase in KWH sales due to higher demand. These transactions had no significant effect on net income, since the energy is generally sold at variable cost.

     Sales for resale — affiliates.Sales for resale — affiliates increased $0.2 million in the first quarter of 2006 compared to the first quarter of 2005. Energy sales to affiliated companies within the Southern Company system will vary depending on demand, and the availability and cost of generating resources at each company. These sales are made in accordance with the IIC, as approved by the FERC. These transactions do not have a

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significant impact on earnings since this energy is generally sold at marginal cost and energy purchases are generally offset by energy revenues through Savannah Electric’s fuel cost recovery clause.

     Other revenues.Other revenues increased 74% in the first quarter 2006 when compared to the corresponding period in 2005. The increase was primarily due to revenues associated with a transmission facilities agreement with Georgia Power related to the Plant McIntosh combined cycle units and to an increase in miscellaneous service revenues as a result of the 2005 Retail Rate Plan. See Note 3 to the financial statements of Savannah Electric under “Retail Regulatory Matters — Rate Plans” in Item 8 of the Form 10-K for additional information.

     Fuel expense, purchased power expense — non-affiliates, and purchased power expense — affiliates. Total fuel expense, purchased power expense — non-affiliates and purchase power expense — affiliates increased $4.3 million in the first quarter of 2006 compared to the same period in 2005 due to a $7.0 million, or 27.2%, increase in the cost of fuel offset by a $2.7 million decrease due to a decrease in net KWHs generated and purchased. Details of the individual components follow.

The 97.8% increase in fuel expense in the first quarter 2006 also reflects the completion of the Plant McIntosh combined cycle units which were placed in service in June 2005. Since fuel expenses are generally offset by fuel revenues through Savannah Electric’s fuel cost recovery clause, these expenses do not have a significant impact on net income. See FUTURE EARNINGS POTENTIAL — “FERC and Georgia PSC Matters — Fuel Cost Recovery” and Note (H) to the Condensed Financial Statements herein for additional information.

Purchased power from non-affiliates will vary depending on the market cost of available energy as compared to the cost of Southern Company system generated energy, demand for energy within the service territory, and availability of Southern Company system generation. The 18.9% increase in purchased power expense in the first quarter 2006 when compared to the corresponding period in 2005 resulted from an increase in the average cost per KWH purchased of 10.1%. These transactions do not have a significant impact on earnings, as energy costs are generally recovered through Savannah Electric’s fuel cost recovery clause.

     Other operations expense.The $2.5 million increase in other operations expense in the first quarter 2006 over the same period in 2005 is primarily due to severance and other costs associated with the Merger, increased salary expense as a result of the expensing of stock options, and increases in other benefits expenses. See ACCOUNTING POLICIES — “New Accounting Standards” and Note (C) to the Condensed Financial Statements herein for additional information on the impact of FASB Statement No. 123R.

     Maintenance expense.Maintenance expense decreased 6.4% for the first quarter 2006 when compared to the same period in 2005 as a result of the timing of distribution expenses primarily related to tree trimming.

     Depreciation and amortization expense.Depreciation and amortization expense increased 11.6% for the first quarter 2006 compared to the same period in 2005 as a result of the completion of the amortization of the regulatory liability for accelerated depreciation in 2005 in accordance with the 2002 Georgia PSC rate order and the addition of the McIntosh combined cycle facilities in June 2005, partially offset by the lowering of the

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composite depreciation rate as part of the 2005 Retail Rate Plan. See Note 3 to the financial statements of Savannah Electric under “Retail Regulatory Matters — Rate Plans” in Item 8 of the Form 10-K for additional information.

     Taxes other than income taxes. In the first quarter 2006, taxes other than income taxes were $0.3 million higher as compared to the same period in 2005 primarily due to increased franchise taxes resulting from increases in operating revenues.

     Interest expense, net of amounts capitalized.Interest expense increased in the first quarter 2006 by 29.4% when compared to the corresponding period in 2005, primarily due to an increase in short-term borrowings and higher interest rates and a decrease in the debt component of AFUDC as a result of the commercial operation of the Plant McIntosh combined cycle project in June 2005.

     Other income (expense), net.In the first quarter 2006, other income decreased $1.2 million as compared to the same period in 2005 primarily as a result of a $1.0 million decrease in non-taxable AFUDC equity following the commercial operation of the Plant McIntosh combined cycle project in June 2005, and as a result of benefits expenses associated with the Merger.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Savannah Electric’s future earnings potential. The level of future earnings depends on numerous factors that affect the opportunities, challenges, and risks of Savannah Electric’s primary business of selling electricity. These factors include Savannah Electric’s ability to maintain a stable regulatory environment that continues to allow for the recovery of all prudently incurred costs. Future earnings in the near term will depend, in part, upon growth in energy sales, which is subject to a number of factors. These factors include weather, competition, energy conservation practiced by customers, the price of electricity, the price elasticity of demand, and the rate of economic growth in Savannah Electric’s service area. For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL of Savannah Electric in Item 7 of the Form 10-K.

Environmental Matters

Compliance costs related to the Clean Air Act and other environmental regulations could affect earnings if such costs cannot be fully recovered in rates on a timely basis. For additional information, including information on certain environmental litigation, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters” of Savannah Electric in Item 7 and Note 3 to the financial statements of Savannah Electric under “New Source Review Actions” in Item 8 of the Form 10-K.

New Source Review Reform Rules

On October 20, 2005, the EPA published a proposed rule clarifying the test for determining when an emissions increase is subject to the NSR requirements. On March 17, 2006, the U.S. Court of Appeals for the District of Columbia Circuit vacated the EPA’s proposed rule which sought to clarify the scope of the existing Routine Maintenance, Repair, and Replacement Exclusion. Because this rule was not yet in effect, the court’s ruling is not anticipated to have any impact on Savannah Electric. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Actions” of Savannah Electric in Item 7 and Note 3 to the financial statements of Savannah Electric under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K for additional information.

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FERC and Georgia PSC Matters

Market-Based Rate Authority

See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Market-Based Rate Authority” of Savannah Electric in Item 7 and Note 3 to the financial statements of Savannah Electric under “FERC Matters — Market-Based Rate Authority” in Item 8 of the Form 10-K for information on the FERC’s April 2004 order adopting a new interim analysis for measuring generation market power and a proceeding initiated by the FERC in December 2004 to assess Southern Company’s generation dominance within its retail service territory. Savannah Electric has authorization from the FERC to sell power to non-affiliates at market-based prices. Savannah Electric also has 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. On February 15, 2005, Southern Company submitted additional information related to generation dominance in its retail service territory. A hearing before an administrative law judge scheduled for March 2006 has been held in abeyance to allow the parties to explore settlement. Any new market-based rate transactions in its 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. The impact of such sales through March 31, 2006 is not expected to exceed $0.4 million for Savannah Electric. The refund period covers 15 months. In the event that the FERC’s default mitigation measures are ultimately applied, Savannah Electric 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 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.

     In addition, in May 2005, the FERC initiated an investigation to determine whether Southern Company satisfies the other three parts of the FERC’s market-based rate analysis: transmission market power, barriers to entry, and affiliate abuse or reciprocal dealing. The FERC established a new 15-month refund period related to this expanded investigation. Any new market-based rate transactions involving any Southern Company subsidiary will be subject to refund to the extent the FERC orders lower rates as a result of this new investigation, with the refund period beginning July 19, 2005. The impact of such sales involving Savannah Electric through March 31, 2006 is not expected to exceed $0.7 million, of which $0.2 million relates to sales inside the retail service territory discussed above. The FERC also directed that this expanded proceeding be held in abeyance pending the outcome of the proceeding on the IIC discussed below.

     Savannah Electric believes that there is no meritorious basis for this proceeding and is vigorously defending itself in this matter. However, the final outcome of this matter, including any remedies to be applied in the event of an adverse ruling in this proceeding, cannot now be determined.

Intercompany Interchange Contract

Also in May 2005, the FERC initiated a new proceeding to examine (1) the provisions of the IIC among Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, Southern Power, and SCS, as agent, under the terms of which the power pool of Southern Company is operated, and, in particular, the propriety of the continued inclusion of Southern Power as a party to the IIC, (2) whether any parties to the IIC have violated the FERC’s standards of conduct applicable to utility companies that are transmission providers, and (3) whether Southern Company’s code of conduct defining Southern Power as a “system company” rather than a “marketing affiliate” is just and reasonable. In connection with the formation of Southern Power, the FERC authorized Southern Power’s inclusion in the IIC in 2000. The FERC also previously approved Southern Company’s code of conduct. The FERC order directs that the administrative law judge who presided over a proceeding involving approval of PPAs between Southern Power and Georgia

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Power and Savannah Electric be assigned to preside over the hearing in this proceeding and that the testimony and exhibits presented in that proceeding be preserved to the extent appropriate. Effective July 19, 2005, revenues from transactions under the IIC involving any Southern Company subsidiaries will be subject to refund to the extent the FERC orders any changes to the IIC. On April 11, 2006, Southern Company, Calpine Corporation, Coral Energy, and Dalton Utilities filed a settlement offer that would resolve the proceeding. The offer is pending before the FERC and does not require any refunds. However, because the offer is pending, the final outcome of this matter cannot now be determined.See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Intercompany Interchange Contract” of Savannah Electric in Item 7 and Note 3 to the financial statements of Savannah Electric under “FERC Matters — Intercompany Interchange Contract” in Item 8 of the Form 10-K for additional information.

Retail Fuel Cost Recovery

On March 17, 2006, Georgia Power and Savannah Electric filed a combined request for fuel cost recovery rate changes with the Georgia PSC to be effective July 1, 2006. The requested changes will allow for the recovery of fuel costs based on an estimate of future fuel costs, as well as the collection of the existing under recovered fuel expenses. The filing also includes proposed rate changes related to the previously announced proposed merger of the two companies, which is expected to be completed by July 2006.

     The request would result in an increase of about $7.22 per month, or about 8.1%, on the average Georgia Power residential customer bill and a decrease of about $8.14 a month, or about 6.4%, on the average residential bill for a customer in the former Savannah Electric territory. Increases for business customers would depend upon the customer’s specific rate class and usage.

     The proposal would increase Georgia Power’s revenues by $556 million a year, of which approximately $106 million relates to collection of the existing under recovered fuel costs. As of the end of March 2006, Savannah Electric had an under recovered fuel balance of $81 million, and Georgia Power had an under recovered fuel balance of about $784 million, including approximately $392 million related to fuel used since June 2005. The proposed fuel rates are based on an amortization period of 35 months for Georgia Power customers and 41 months for former Savannah Electric territory customers. Hearings are scheduled for May 2006 and the Georgia PSC is expected to rule on this matter in June 2006. The outcome of this matter cannot be determined at this time. See Note 3 to the financial statements of Savannah Electric under “Retail Regulatory Matters — Fuel Cost Recovery” in Item 8 of the Form 10-K and Note (H) to the Condensed Financial Statements herein for additional information.

Other Matters

Savannah Electric is subject to certain claims and legal actions arising in the ordinary course of business. In addition, Savannah Electric’s business activities are subject to extensive governmental regulation related to public health and the environment. Litigation over environmental issues and claims of various types, including property damage, personal injury, and citizen enforcement of environmental requirements such as opacity and other air quality standards, 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. The ultimate outcome of such pending or potential litigation against Savannah Electric cannot be predicted at this time; however, for current proceedings not specifically reported herein or in Note 3 to the financial statements of Savannah Electric in Item 8 of the Form 10-K, management does not anticipate that the liabilities, if any, arising from such proceedings would have a material adverse effect on Savannah Electric’s financial statements.

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     See the Notes to the Condensed Financial Statements herein for discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Savannah Electric prepares its financial statements in accordance with accounting principles generally accepted in the United States. Significant accounting policies are described in Note 1 to the financial statements of Savannah Electric in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on Savannah Electric’s results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT’S DISCUSSION AND ANALYSIS — ACCOUNTING POLICIES — “Application of Critical Accounting Policies and Estimates” of Savannah Electric in Item 7 of the Form 10-K for a complete discussion of Savannah Electric’s critical accounting policies and estimates related to Electric Utility Regulation, Contingent Obligations, and Unbilled Revenues.

New Accounting Standards

On January 1, 2006, Savannah Electric adopted FASB Statement No. 123(R), “Share-Based Payment,” using the modified prospective method. This statement requires that compensation cost relating to share-based payment transactions be recognized in the financial statements. That cost will be measured based on the grant date fair value of the equity or liability instruments issued. Although the compensation expense required under the revised statement differs slightly, the impacts on Savannah Electric’s financial statements are similar to the pro forma disclosures previously included in Note 1 to the financial statements of Savannah Electric under “Stock Options” in Item 8 of the Form 10-K and in Note (C) to the Condensed Financial Statements herein. Total pre-tax compensation cost related to non-vested awards not yet recognized is expected to be approximately $0.2 million over the remaining three-year service period.

FINANCIAL CONDITION AND LIQUIDITY

Overview

Savannah Electric’s financial condition remained stable at March 31, 2006. Net cash flow provided from (used for) operating activities totaled $(0.3) million for the first quarter of 2006, compared to $(2.8) million for the first quarter of 2005. The $2.5 million increase in 2006 resulted primarily from increases in base rates and the fuel cost recovery factor. Major changes in Savannah Electric’s financial condition during the first quarter of 2006 included the addition of approximately $9.9 million to utility plant. The funds for these additions and other capital requirements were derived primarily from operations and routine financing activities. See Savannah Electric’s Condensed Statements of Cash Flows herein for further details.

Capital Requirements and Contractual Obligations

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Capital Requirements and Contractual Obligations” of Savannah Electric in Item 7 of the Form 10-K for a description of Savannah Electric’s capital requirements for its construction program, lease obligations, preferred stock dividends, purchase commitments, and trust funding requirements. Approximately $21 million will be required by March 31, 2007 for redemptions and maturities of long-term debt.

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Sources of Capital

Savannah Electric plans to obtain the funds required for construction and other purposes from sources similar to those used in the past, including funds from operations, capital contributions from Southern Company, and short-term debt. The amount, type, and timing of any future financings, if needed, will depend upon maintenance of adequate earnings, regulatory approval, prevailing market conditions, and other factors. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Sources of Capital” of Savannah Electric in Item 7 of the Form 10-K for additional information.

     Savannah Electric’s current liabilities exceed current assets due to the maturity of $21 million of long-term debt in 2006. To meet short-term cash needs and contingencies, Savannah Electric had at March 31, 2006 approximately $3.2 million of cash and cash equivalents and $80 million of unused committed credit arrangements with banks, of which $60 million expire in 2006 and the remaining $20 million expires in 2008. All of the unused credit arrangements expiring in 2006 include two-year term loan options executable at the expiration date. The credit arrangements provide liquidity support to some of Savannah Electric’s obligations with respect to variable rate debt and commercial paper. Savannah Electric expects to renew its credit facilities, as needed, prior to expiration. See Note 6 to the financial statements of Savannah Electric under “Bank Credit Arrangements” in Item 8 of the Form 10-K for additional information. Savannah Electric may also meet short-term cash needs through a Southern Company subsidiary organized to issue and sell commercial paper and extendible commercial notes at the request and for the benefit of Savannah Electric and other Southern Company subsidiaries. At March 31, 2006, Savannah Electric had $37.5 million of outstanding commercial paper and $14.1 million of outstanding extendible commercial notes.

Credit Rating Risk

Savannah Electric does not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. Savannah Electric, along with all members of the Southern Company power pool, is also party to certain derivatives agreements that could require collateral and/or accelerated payment in the event of a credit rating change to below investment grade for Alabama Power and/or Georgia Power. These agreements are primarily for natural gas price and interest rate risk management activities. At March 31, 2006, Savannah Electric’s total exposure to these types of agreements was approximately $11 million.

Market Price Risk

Savannah Electric’s market risk exposures relative to interest rate changes have not changed materially compared with the December 31, 2005 reporting period. In addition, Savannah Electric is not aware of any facts or circumstances that would significantly affect such exposures in the near term.

     Due to cost-based rate regulations, Savannah Electric has limited exposure to market volatility in interest rates, commodity fuel prices, and prices of electricity. To mitigate residual risks relative to movements in electricity prices, Savannah Electric enters into fixed-price contracts for the purchase and sale of electricity through the wholesale electricity market. Savannah Electric has also implemented a retail fuel hedging program at the instruction of the Georgia PSC.

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     The fair value of derivative energy contracts at March 31, 2006 was as follows:

	First Quarter
	2006
	Changes
	Fair Value
	(in thousands)
Contracts beginning of period	$	8,748
Contracts realized or settled		(1,438	)
New contracts at inception		—
Changes in valuation techniques		—
Current period changes (a)		(6,457	)
Contracts at March 31, 2006	$	853

(a) Current period changes also include the changes in fair value of new contracts entered into during the period.

	Source of March 31, 2006
	Valuation Prices
			Maturity
	Total
	Fair Value		Year 1			1-3 Years
	(in thousands)
Actively quoted	$	853	$	(1,034	)	$	1,887
External sources		—		—			—
Models and other methods		—		—			—
Contracts at March 31, 2006	$	853	$	(1,034	)	$	1,887

     Unrealized gains and losses from mark-to-market adjustments on derivative contracts related to Savannah Electric’s fuel hedging program are recorded as regulatory assets and liabilities. Realized gains and losses from this program are included in fuel expense and recovered through Savannah Electric’s fuel cost recovery clause. Of the net gains, Savannah Electric is allowed to retain 25% in earnings. Gains and losses on derivative contracts that are not designated as hedges are recognized in the statements of income as incurred. These amounts were not material in any period presented. At March 31, 2006, the fair value gain/(loss) of derivative energy contracts was reflected in the financial statements as follows:

	Amounts
	(in thousands)
Regulatory liabilities, net	$	853
Accumulated other comprehensive income		—
Net income		—
Total fair value gain	$	853

     For additional information, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Market Price Risk” of Savannah Electric in Item 7 and Notes 1 and 6 to the financial statements of Savannah Electric under “Financial Instruments” in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein.

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Financing Activities

Savannah Electric did not issue or redeem any long-term securities in the first quarter of 2006. In February 2006, Savannah Electric received a capital contribution from Southern Company of $30 million. In addition to any financings that may be necessary to meet capital requirements and contractual obligations, Savannah Electric plans to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit. If the Merger is completed, all future financings for Savannah operations will be assumed by Georgia Power.

     Subsequent to March 31, 2006, a cash flow hedge with a $30 million notional amount used to hedge the interest exposure arising from a forecasted debt issuance in May 2006 was terminated at a gain of $2.1 million. The fair value gain at March 31, 2006 of $1.6 million will remain in other comprehensive income and be reclassified to income over a 10-year period if the debt issuance actually occurs; otherwise the gain will be recognized immediately in income. This decision will be based mainly upon the outcome of the Merger. The change in fair value of $0.5 million subsequent to March 31, 2006 will be recognized in income in the second quarter 2006.

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SOUTHERN POWER COMPANY

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Revenues:
Sales for resale —
Non-affiliates	$	51,697		$	40,104
Affiliates		87,323			112,337
Other revenues		809			380
Total operating revenues		139,829			152,821
Operating Expenses:
Fuel		14,259			34,544
Purchased power —
Non-affiliates		13,971			8,862
Affiliates		19,407			20,954
Other operations		17,507			12,719
Maintenance		5,885			3,259
Depreciation and amortization		14,707			12,783
Taxes other than income taxes		3,661			2,955
Total operating expenses		89,397			96,076
Operating Income		50,432			56,745
Other Income and (Expense):
Interest expense, net of amounts capitalized		(20,342	)		(19,244	)
Other income (expense), net		2,403			92
Total other income and (expense)		(17,939	)		(19,152	)
Earnings Before Income Taxes		32,493			37,593
Income taxes		12,593			14,520
Net Income	$	19,900		$	23,073

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Net Income	$	19,900		$	23,073
Other comprehensive income (loss):
Changes in fair value of qualifying hedges, net of tax of $(79)		(122	)		—
Reclassification adjustment for amounts included in net income, net of tax of $1,112 and $1,041, respectively		1,732			1,612
COMPREHENSIVE INCOME	$	21,510		$	24,685

The accompanying notes as they relate to Southern Power are an integral part of these condensed financial statements.

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SOUTHERN POWER COMPANY
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months
	Ended March 31,
	2006			2005
	(in thousands)
Operating Activities:
Net income	$	19,900		$	23,073
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization		18,070			16,448
Deferred income taxes and investment tax credits, net		17,251			15,598
Deferred revenues		(26,672	)		(26,194	)
Tax benefit of stock options		—			188
Other, net		3,480			(538	)
Changes in certain current assets and liabilities —
Receivables		38,672			964
Fossil fuel stock		(293	)		593
Materials and supplies		(356	)		(232	)
Other current assets		(8,517	)		(3,894	)
Accounts payable		(46,701	)		(6,148	)
Accrued taxes		2,899			3,014
Accrued interest		(15,365	)		(15,598	)
Net cash provided from operating activities		2,368			7,274
Investing Activities:
Property additions		(1,175	)		(2,075	)
Other		2			(2,413	)
Net cash used for investing activities		(1,173	)		(4,488	)
Financing Activities:
Increase in notes payable, net		231			—
Payment of common stock dividends		(19,425	)		—
Net cash used for financing activities		(19,194	)		—
Net Change in Cash and Cash Equivalents		(17,999	)		2,786
Cash and Cash Equivalents at Beginning of Period		27,631			25,241
Cash and Cash Equivalents at End of Period	$	9,632		$	28,027
Supplemental Cash Flow Information:
Cash paid during the period for — Interest (net of $0 and $0 capitalized for 2006 and 2005, respectively)	$	32,260		$	31,073
— Income taxes (net of refunds)	$	4,227		$	3,593

The accompanying notes as they relate to Southern Power are an integral part of these condensed financial statements.

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CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

	At March 31,		At December 31,
Assets	2006		2005
	(in thousands)
Current Assets:
Cash and cash equivalents	$	9,632	$	27,631
Receivables —
Customer accounts receivable		20,400		20,953
Other accounts receivable		71		93
Affiliated companies		38,161		60,505
Fossil fuel stock, at average cost		7,514		7,221
Materials and supplies, at average cost		15,984		15,628
Prepaid service agreement — current		19,829		6,178
Other prepaid expenses		9,072		4,610
Other		2,415		251
Total current assets		123,078		143,070
Property, Plant, and Equipment:
In service		2,030,150		2,030,996
Less accumulated provision for depreciation		171,817		161,358
		1,858,333		1,869,638
Construction work in progress		203,254		218,812
Total property, plant, and equipment		2,061,587		2,088,450
Deferred Charges and Other Assets:
Prepaid long-term service agreements		31,659		46,447
Other—
Affiliated		5,770		4,496
Other		19,062		20,513
Total deferred charges and other assets		56,491		71,456
Total Assets	$	2,241,156	$	2,302,976

The accompanying notes as they relate to Southern Power are an integral part of these condensed financial statements.

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SOUTHERN POWER COMPANY
CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

	At March 31,			At December 31,
Liabilities and Stockholder’s Equity	2006			2005
	(in thousands)
Current Liabilities:
Securities due within one year	$	200		$	200
Notes payable		110,923			110,692
Accounts payable —
Affiliated		21,687			65,262
Other		4,513			7,651
Accrued taxes —
Income taxes		—			3,477
Other		5,424			2,524
Accrued interest		13,796			29,161
Other		214			71
Total current liabilities		156,757			219,038
Long-term Debt		1,099,569			1,099,520
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes		87,896			68,535
Deferred capacity revenues — Affiliated		12,869			37,534
Other —
Affiliated		9,458			10,792
Other		6,178			1,214
Total deferred credits and other liabilities		116,401			118,075
Total Liabilities		1,372,727			1,436,633
Common Stockholder’s Equity:
Common stock, par value $.01 per share —
Authorized - 1,000,000 shares
Outstanding - 1,000 shares		—			—
Paid-in capital		746,244			746,243
Retained earnings		165,000			164,525
Accumulated other comprehensive loss		(42,815	)		(44,425	)
Total common stockholder’s equity		868,429			866,343
Total Liabilities and Stockholder’s Equity	$	2,241,156		$	2,302,976

The accompanying notes as they relate to Southern Power are an integral part of these condensed financial statements.

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SOUTHERN POWER COMPANY

MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FIRST QUARTER 2006 vs. FIRST QUARTER 2005

OVERVIEW

Southern Power constructs, owns, and manages Southern Company’s competitive generation assets and sells electricity at market-based rates in the Super Southeast wholesale market. Southern Power continues to focus on executing its regional strategy in the Super Southeast in 2006, including potential acquisition and/or expansion opportunities. Southern Power continues to address questions at the federal regulatory level relative to market power and affiliate transactions. See FUTURE EARNINGS POTENTIAL-“FERC Matters” herein for additional detail.

     To evaluate operating results and to ensure Southern Power’s ability to meet its contractual commitments to customers, Southern Power focuses on several key performance indicators. These indicators consist of plant availability, peak season equivalent forced outage rate (EFOR), and net income. Plant availability shows the percentage of time during the year that Southern Power’s generating units are available to be called upon to generate (the higher the better), whereas the EFOR more narrowly defines the hours during peak demand times when Southern Power’s generating units are not available due to forced outages (the lower the better). For additional information on these indicators, see MANAGEMENT’S DISCUSSION AND ANALYSIS — OVERVIEW — “Key Performance Indicators” of Southern Power in Item 7 of the Form 10-K.

RESULTS OF OPERATIONS

Earnings

Southern Power’s net income for the first quarter 2006 was $19.9 million compared to $23.1 million for the corresponding period of 2005. The decrease in first quarter 2006 earnings of $3.2 million, or 13.8%, was primarily the result of the decreased demand under affiliate company PPAs due to milder weather within the Southern Company service territory and the timing of maintenance activities. This decrease was partially offset by the operations of Plant Oleander acquired in June 2005 and a new contract with Piedmont Municipal Power Authority (PMPA).

     Significant income statement items appropriate for discussion include the following:

	Increase (Decrease)
	First Quarter
	(in thousands)			%
Sales for resale — non-affiliates	$	11,593			28.9
Sales for resale — affiliates		(25,014	)		(22.3	)
Fuel expense		(20,285	)		(58.7	)
Purchased power expense — non-affiliates		5,109			57.7
Purchased power expense — affiliates		(1,547	)		(7.4	)
Other operations expense		4,788			37.6
Maintenance expense		2,626			80.6
Depreciation and amortization expense		1,924			15.1
Interest expense, net of amounts capitalized		(1,098	)		(5.7	)
Other income (expense), net		2,311			N/M
N/M — Not meaningful

     Sales for resale—affiliates and non-affiliates. First quarter 2006 revenues from sales for resale to non-affiliates increased and sales for resale to affiliates decreased compared to the corresponding period in 2005. The increase in revenues from non-affiliates was primarily due to PPA sales from Plant Oleander. The decrease in revenues from affiliates was primarily due to lower energy sales under existing PPAs with affiliates as a result of decreased demand

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SOUTHERN POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

related to milder weather and scheduled maintenance outages, largely offset by reductions in fuel expense. See FUTURE EARNINGS POTENTIAL — “Power Sales Agreements” of Southern Power in Item 7 of the Form 10-K.

     Fuel expense. Fuel expense in the first quarter 2006 decreased when compared to the same period in 2005 due to a decline in energy sales under PPAs with affiliates. Existing PPAs generally provide that the purchasers are responsible for substantially all of the fuel costs relating to energy delivered under the PPAs; therefore, fuel expenses do not have a significant impact on net income.

     Purchased power expense—affiliates and non-affiliates. Total purchased power increased in the first quarter 2006 when compared to the same period in 2005. During the first quarter of 2006, purchased power from non-affiliates increased but was partially offset by a decrease in purchased power from affiliates when compared to the corresponding period of 2005. This was primarily due to the availability of lower cost energy from contracts with Georgia electric membership cooperatives and PMPA.

     Other operations expense.Other operations expense increased in the first quarter 2006 when compared to the corresponding period in 2005 primarily due to the operations at Plant Oleander, transmission costs related to the PMPA contract, and increased administrative costs.

     Maintenance expense.Maintenance expense increased in first quarter 2006 when compared to the corresponding period in 2005, primarily as a result of operations at Plant Oleander, a scheduled outage at Plant Wansley, and the timing of maintenance activities at Plant Franklin and Plant Harris.

     Depreciation and amortization expense.Depreciation expense increased in the first quarter 2006 when compared to the corresponding period in 2005, primarily as a result of additional plant in service relating to Plant Oleander, which was acquired in June 2005, and new depreciation rates adopted as of March 1, 2006 as a result of a new depreciation study.

     Interest expense, net of amounts capitalized.Interest expense, net of amounts capitalized increased in the first quarter 2006 when compared to the same period in 2005 primarily as the result of an increase in outstanding short-term debt incurred to finance the Plant Oleander acquisition.

     Other income (expense), net.The $2.3 million increase in other income (expense), net during the first quarter 2006 compared to the same period in 2005 was primarily the result of mark-to-market gains on open derivative positions.

FUTURE EARNINGS POTENTIAL

The results of operations discussed above are not necessarily indicative of Southern Power’s future earnings potential. Several factors affect the opportunities, challenges, and risks of Southern Power’s competitive wholesale energy business. These factors include the ability to achieve sales growth while containing costs. Another major factor is federal regulatory policy, which may impact Southern Power’s level of participation in this market. The level of future earnings depends on numerous factors, especially regulatory matters, including those related to affiliate contracts, sales, creditworthiness of customers, total generating capacity available in the Southeast, and the successful remarketing of capacity as current contracts expire. For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL of Southern Power in Item 7 of the Form 10-K.

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SOUTHERN POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FERC Matters

Market-Based Rate Authority

See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Market-Based Rate Authority” of Southern Power in Item 7 and Note 2 to the financial statements of Southern Power under “FERC Matters — Market-Based Rate Authority” in Item 8 of the Form 10-K for information on the FERC’s April 2004 order adopting a new interim analysis for measuring generation market power and a proceeding initiated by the FERC in December 2004 to assess Southern Company’s generation dominance within its retail service territory. Southern Power has authorization from the FERC to sell power to non-affiliates at market-based prices. Southern Power also has 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. On February 15, 2005, Southern Company submitted additional information related to generation dominance in its retail service territory. A hearing before an administrative law judge scheduled for March 2006 has been held in abeyance to allow the parties to explore settlement. Any new market-based rate transactions in Southern Company’s 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. The impact of such sales through March 31, 2006 is not expected to exceed $0.7 million for Southern Power. The refund period covers 15 months. In the event that the FERC’s default mitigation measures are ultimately applied, Southern Power 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 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.

     In addition, in May 2005, the FERC initiated an investigation to determine whether Southern Company satisfies the other three parts of the FERC’s market-based rate analysis: transmission market power, barriers to entry, and affiliate abuse or reciprocal dealing. The FERC established a new 15-month refund period related to this expanded investigation. Any new market-based rate transactions involving any Southern Company subsidiary will be subject to refund to the extent the FERC orders lower rates as a result of this new investigation, with the refund period beginning July 19, 2005. The impact of such sales involving Southern Power through March 31, 2006 is not expected to exceed $1.9 million, of which $0.5 million relates to sales inside the retail service territory discussed above. The FERC also directed that this expanded proceeding be held in abeyance pending the outcome of the proceeding on the IIC discussed below.

     Southern Power believes that there is no meritorious basis for this proceeding and is vigorously defending itself in this matter. However, the final outcome of this matter, including any remedies to be applied in the event of an adverse ruling in this proceeding, cannot now be determined.

Intercompany Interchange Contract

Also in May 2005, the FERC initiated a new proceeding to examine (1) the provisions of the IIC among Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, Southern Power, and SCS, as agent, under the terms of which the power pool of Southern Company is operated, and, in particular, the propriety of the continued inclusion of Southern Power as a party to the IIC, (2) whether any parties to the IIC have violated the FERC’s standards of conduct applicable to utility companies that are transmission providers, and (3) whether Southern Company’s code of conduct defining Southern Power as a “system company” rather than a “marketing affiliate” is just and reasonable. In connection with the formation of Southern Power, the FERC authorized Southern Power’s inclusion in the IIC in 2000. The FERC also previously approved Southern Company’s code of conduct. The FERC order directs that the administrative law judge who presided over a proceeding involving approval of PPAs between Southern Power and Georgia Power and Savannah Electric be assigned to preside over the hearing in this proceeding and that the testimony and exhibits presented in that proceeding be preserved to the extent appropriate. Effective July 19, 2005, revenues from transactions under the IIC involving any Southern Company subsidiaries will be subject to refund to the extent the FERC orders any changes to the IIC. On April 11, 2006, Southern Company, Calpine Corporation, Coral

107

SOUTHERN POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Energy, and Dalton Utilities filed a settlement offer that would resolve the proceeding. The offer is pending before the FERC and does not require any refunds. However, because the offer is pending, the final outcome of this matter cannot now be determined.See MANAGEMENT’S DISCUSSION AND ANALYSIS— FUTURE EARNINGS POTENTIAL — “FERC Matters — Intercompany Interchange Contract” of Southern Power in Item 7 and Note 2 to the financial statements of Southern Power under “FERC Matters — Intercompany Interchange Contract” in Item 8 of the Form 10-K for additional information.

Other Matters

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Power Sales Agreements” of Southern Power in Item 7 of the Form 10-K for additional information on long-term PPAs. Southern Power’s PPAs with non-affiliated counterparties have provisions that require the posting of collateral or an acceptable substitute guarantee in the event that the counterparty does not meet certain rating or financial requirements. The PPAs are expected to provide Southern Power with a stable source of revenue during their respective terms.

     See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters” of Southern Power in Item 7 of the Form 10-K for information on the development by federal and state environmental regulatory agencies of additional control strategies for emission of air pollution from industrial sources, including electric generating facilities. Compliance costs related to current and future environmental laws and regulations could affect earnings if such costs are not fully recovered. While Southern Power’s PPAs generally contain provisions that permit charging the counterparty with some of the new costs incurred as a result of changes in environmental laws and regulations, the full impact of any such regulatory or legislative changes cannot be determined at this time.

     Southern Power is subject to certain claims and legal actions arising in the ordinary course of business. In addition, Southern Power’s business activities are subject to extensive governmental regulation related to public health and the environment. Litigation over environmental issues and claims of various types, including property damage, personal injury, and citizen enforcement of environmental requirements such as opacity and other air quality standards, 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. The ultimate outcome of such potential litigation against Southern Power cannot be predicted at this time; however, management does not anticipate that the liabilities, if any, arising from any such current proceedings would have a material adverse effect on Southern Power’s financial statements.

     See Note (B) to the Condensed Financial Statements herein for discussion of various other contingencies, regulatory matters, and other matters being litigated which may affect future earnings potential.

ACCOUNTING POLICIES

Application of Critical Accounting Policies and Estimates

Southern Power prepares its financial statements in accordance with accounting principles generally accepted in the United States. Significant accounting policies are described in Note 1 to the financial statements of Southern Power in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on Southern Power’s results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements. See MANAGEMENT’S DISCUSSION AND ANALYSIS— ACCOUNTING POLICIES — “Application of Critical Accounting Policies and Estimates” of Southern Power in Item 7 of the Form 10-K for a complete discussion of Southern Power’s critical accounting policies and estimates related to revenue recognition and asset impairments.

108

SOUTHERN POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

FINANCIAL CONDITION AND LIQUIDITY

Overview

Southern Power’s financial condition remained stable at March 31, 2006. Net cash flow from operating activities decreased $4.9 million for the three months ended March 31, 2006 as compared to the same period in 2005 primarily as a result of lower demand under affiliate company PPAs. Other significant transactions in the three months ended March 31, 2006 included a $19.4 million dividend to Southern Company and the completion of the sale of Cherokee Falls LLC and all of its assets to Southern Company’s nuclear development affiliate.

Capital Requirements and Contractual Obligations

See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY —“Capital Requirements and Contractual Obligations” of Southern Power in Item 7 of the Form 10-K for a description of Southern Power’s capital requirements for its construction program, maturing debt, purchase commitments, and long-term service agreements.

Sources of Capital

Southern Power may use operating cash flows, external funds, or capital contributions from Southern Company to finance any new projects, acquisitions, and ongoing capital requirements. Southern Power expects to generate external funds from commercial paper, the issuance of unsecured senior debt, preferred equity securities, or the utilization of credit arrangements from banks. See MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Sources of Capital” of Southern Power in Item 7 of the Form 10-K for additional information.

     At March 31, 2006, Southern Power’s current liabilities exceeded current assets due to the use of short-term debt as a funding source to finance the Plant Oleander acquisition and for general corporate needs. At March 31, 2006, Southern Power had approximately $9.6 million of cash and cash equivalents to meet short-term cash needs and contingencies. To insure liquidity and capital resource requirements, Southern Power has a $400 million committed credit facility with banks. Proceeds from borrowings under this arrangement may be used for working capital and general corporate purposes as well as liquidity support for Southern Power’s commercial paper program. At March 31, 2006, Southern Power had no outstanding borrowings under its credit facility.

     At March 31, 2006, Southern Power had approximately $110.9 million of commercial paper outstanding. Amounts drawn under the commercial paper program may be used to finance acquisition and construction costs related to electric generating facilities and for general corporate purposes.

Credit Rating Risk

Southern Power does not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change to BBB and Baa2 or to BBB- or Baa3 or below. Generally, collateral may be provided with a Southern Company guaranty, letter of credit, or cash. These contracts are primarily for physical electricity purchases and sales. At March 31, 2006, the maximum potential collateral requirements at a BBB and Baa2 rating were approximately $9 million and at a BBB- or Baa3 rating were approximately $221 million. The maximum potential collateral requirements at a rating below BBB- or Baa3 were approximately $339 million. Southern Power, along with all members of the Southern Company power pool, is also party to certain derivative agreements that could require collateral and/or accelerated payment in the event of a credit rating change to below investment grade for Alabama Power and/or Georgia Power. These agreements are primarily for natural gas price risk management activities. At March 31, 2006, Southern Power’s total exposure to these types of agreements was approximately $11 million.

109

SOUTHERN POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

Market Price Risk

Southern Power is exposed to market risks, including changes in interest rates, certain energy-related commodity prices, and, occasionally, currency exchange rates. To manage the volatility attributable to these exposures, Southern Power nets the exposures to take advantage of natural offsets and enters into various derivative transactions for the remaining exposures pursuant to Southern Power’s policies in areas such as counterparty exposure and hedging practices. Southern Power’s policy is that derivatives are to be used primarily for hedging purposes. Derivative positions are monitored using techniques that include market valuation and sensitivity analysis.

     Southern Power’s market risk exposures relative to interest rate changes have not changed materially compared with the December 31, 2005 reporting period. In addition, Southern Power is not aware of any facts or circumstances that would significantly affect such exposures in the near term.

     Because energy from Southern Power’s generating facilities is primarily sold under long-term PPAs with tolling agreements and provisions shifting substantially all of the responsibility for fuel cost to the purchasers, Southern Power’s exposure to market volatility in commodity fuel prices and prices of electricity is limited. To mitigate residual risks in those areas, Southern Power enters into fixed-price contracts for the sale of electricity.

     The fair value of changes in derivative energy contracts at March 31, 2006 was as follows:

	First Quarter 2006 Changes
	Fair Value
	(in thousands)
Contracts beginning of year	$	223
Contracts realized or settled		56
New contracts at inception		—
Current period changes (a)		1,961
Contracts at March 31, 2006	$	2,240

(a) Current period changes also include the changes in fair value of new contracts entered into during the period.

     At March 31, 2006, the sources of the valuation prices were as follows:

	Total			Maturity
	Fair Value			Year 1			1-3 Years
	(in thousands)
Actively quoted	$	2,241		$	2,203		$	38
External sources		(1	)		(1	)		—
Models and other methods		—			—			—
Contracts end of quarter	$	2,240		$	2,202		$	38

     Unrealized pre-tax gains and losses on electric contracts used to hedge anticipated sales, and gas contracts used to hedge anticipated purchases and sales, are deferred in Other Comprehensive Income. Realized gains and losses on contracts that do not represent hedges are recognized in the statements of income as incurred.

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SOUTHERN POWER COMPANY
MANAGEMENT’S DISCUSSION AND ANALYSIS OF
FINANCIAL CONDITION AND RESULTS OF OPERATIONS

     At March 31, 2006, the fair value gain/(loss) of derivative energy contracts was as follows:

	Amounts
	(in thousands)
Net Income	$	2,379
Accumulated other comprehensive income		(139	)
Total fair value gain	$	2,240

     For additional information, see MANAGEMENT’S DISCUSSION AND ANALYSIS — FINANCIAL CONDITION AND LIQUIDITY — “Market Price Risk” of Southern Power in Item 7 and Notes 1 and 5 to the financial statements of Southern Power under “Financial Instruments” in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein.

111

NOTES TO THE CONDENSED FINANCIAL STATEMENTS
FOR
THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES
ALABAMA POWER COMPANY
GEORGIA POWER COMPANY
GULF POWER COMPANY
MISSISSIPPI POWER COMPANY
SAVANNAH ELECTRIC AND POWER COMPANY
SOUTHERN POWER COMPANY

INDEX TO APPLICABLE NOTES TO
FINANCIAL STATEMENTS BY REGISTRANT

Registrant	Applicable Notes
Southern Company	A, B, C, D, E, F, G, H, I, J, K
Alabama Power	A, B, C, D, F, G, J
Georgia Power	A, B, C, D, F, G, H
Gulf Power	A, B, C, D, F, G
Mississippi Power	A, B, C, D, F, G, I
Savannah Electric	A, B, C, D, F, G, H, J
Southern Power	A, B, F

112

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES
ALABAMA POWER COMPANY
GEORGIA POWER COMPANY
GULF POWER COMPANY
MISSISSIPPI POWER COMPANY
SAVANNAH ELECTRIC AND POWER COMPANY
SOUTHERN POWER COMPANY

NOTES TO THE CONDENSED FINANCIAL STATEMENTS:

(A)	The condensed quarterly financial statements of the registrants included herein have been prepared by each registrant, without audit, pursuant to the rules and regulations of the SEC. The condensed balance sheets as of December 31, 2005 have been derived from the audited financial statements. In the opinion of each registrant’s management, the information regarding such registrant furnished herein reflects all adjustments necessary to present fairly the results of operations for the periods ended March 31, 2006 and 2005. Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States have been condensed or omitted pursuant to such rules and regulations, although each registrant believes that the disclosures regarding such registrant are adequate to make the information presented not misleading. Disclosure which would substantially duplicate the disclosure in the Form 10-K and details which have not changed significantly in amount or composition since the filing of the Form 10-K are omitted from this Quarterly Report on Form 10-Q. Therefore, these condensed financial statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. Certain prior period amounts have been reclassified to conform to current period presentation. Due to seasonal variations in the demand for energy, operating results for the periods presented do not necessarily indicate operating results for the entire year.
(B)	See Note 3 to the financial statements of Southern Company and the retail operating companies and Note 2 to the financial statements of Southern Power in Item 8 of the Form 10-K for information relating to various lawsuits and other contingencies.
	NEW SOURCE REVIEW ACTIONS
	New Source Review Litigation
	See MANAGEMENT’S DISCUSSION AND ANALYSIS — FUTURE EARNINGS POTENTIAL — “Environmental Matters — New Source Review Actions” of Southern Company and Alabama Power in Item 7 and Note 3 to the financial statements of Southern Company and Alabama Power under “Environmental Matters — New Source Review Actions” in Item 8 of the Form 10-K for additional information regarding a civil action brought by the EPA alleging that Alabama Power had violated the NSR provisions of the Clean Air Act and related state laws with respect to certain of its coal-fired generating facilities. On April 24, 2006, as a result of court-ordered mediation, the EPA filed, with the U.S. District Court for the Northern District of Alabama, statements designed to result in a judgment being entered in favor of Alabama Power on the claims related to Plants Barry, Gaston, Gorgas, and Greene County. In turn, Alabama Power agreed to the filing with the district court of a proposed consent decree that, upon such court’s approval, would require Alabama Power to pay $100,000 to resolve the EPA’s claim for a civil penalty related to alleged violations at Plant Miller. The proposed consent decree also formalizes specific emissions reductions to be accomplished by Alabama Power. These reductions are consistent with other Clean Air Act programs that require emissions reductions. Alabama Power further agreed to donate $4.9 million of sulfur dioxide emission allowances to a nonprofit charitable organization. As a result, Alabama Power recognized $5 million in other income (expense), net related to the proposed consent decree. The final resolution of these claims is dependent on further court action and subject to possible appeals, and therefore, cannot be determined at this time.

113

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

New Source Review Reform Rules

On October 20, 2005, the EPA published a proposed rule clarifying the test for determining when an emissions increase is subject to the NSR requirements. On March 17, 2006, the U.S. Court of Appeals for the District of Columbia Circuit vacated the EPA’s proposed rule which sought to clarify the scope of the existing Routine Maintenance, Repair, and Replacement Exclusion. Because this rule was not yet in effect, the court’s ruling is not anticipated to have any impact on Southern Company or its subsidiaries.

PLANT WANSLEY ENVIRONMENTAL LITIGATION

On March 30, 2006, the U.S. Court of Appeals for the Eleventh Circuit ruled in favor of Georgia Power on its appeal and reversed the district court’s order regarding certain alleged opacity violations at Plant Wansley. The court of appeals remanded the case to the U.S. District Court for the Northern District of Georgia for further proceedings consistent with its decision. The ultimate outcome of this matter cannot now be determined. See Note 3 to the financial statements of Southern Company and Georgia Power under “Environmental Matters — Plant Wansley Environmental Litigation” in Item 8 of the Form 10-K for additional information.

MIRANT MATTERS

Mirant was an energy company with businesses that included independent power projects and energy trading and risk management companies in the U.S. and selected other countries. It was a wholly-owned subsidiary of Southern Company until its initial public offering in October 2000. In April 2001, Southern Company completed a spin-off to its shareholders of its remaining ownership, and Mirant became an independent corporate entity. In July 2003, Mirant filed for voluntary reorganization under Chapter 11 of the Bankruptcy Code. See Note 3 to the financial statements of Southern Company under “Mirant Matters — Mirant Bankruptcy” in Item 8 of the Form 10-K for information regarding Southern Company’s contingent liabilities associated with Mirant, including guarantees of contractual commitments, litigation, and joint and several liabilities in connection with the consolidated federal income tax return.

Mirant Securities Litigation

See Note 3 to the financial statements of Southern Company under “Mirant Matters — Mirant Securities Litigation” in Item 8 of the Form 10-K for information regarding a class action lawsuit that several Mirant shareholders (plaintiffs) originally filed against Mirant and certain Mirant officers in May 2002. In November 2002, Southern Company, certain former and current senior officers of Southern Company, and 12 underwriters of Mirant’s initial public offering were added as defendants. On March 24, 2006, the plaintiffs filed a Motion for Reconsideration requesting that the court vacate that portion of its July 14, 2003 order dismissing the plaintiffs’ claims based upon Mirant’s alleged improper energy trading and marketing activities involving the California energy market. Southern Company and the other defendants have opposed the plaintiffs’ motion. The plaintiffs have also stated that they intend to request that the court grant leave for them to amend the complaint to add allegations based upon claims asserted against Southern Company in the Mirant bankruptcy litigation. See Note 3 to the financial statements of Southern Company under “Mirant Matters — Mirant Bankruptcy Litigation” in Item 8 of the Form 10-K for additional information. The ultimate outcome of these matters cannot be determined at this time.

Southern Company Employee Savings Plan Litigation

See Note 3 to the financial statements of Southern Company under “Mirant Matters — Southern Company Employee Savings Plan Litigation” in Item 8 of the Form 10-K for information related to the class action complaint filed under ERISA on behalf of a purported class of participants in or beneficiaries of The Southern Company Employee Savings Plan at any time since April 2, 2001 and whose plan accounts

114

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

included investments in Mirant common stock. In April 2006, the U.S. District Court for the Northern District of Georgia granted summary judgment in favor of Southern Company and all individually named defendants in the case. The plaintiff has filed an appeal of the ruling. The final outcome of this matter cannot be determined at this time.

FERC MATTERS

See Note 3 to the financial statements of Southern Company, Alabama Power, Georgia Power, Gulf Power, Mississippi Power, and Savannah Electric under “FERC Matters — Market-Based Rate Authority” and Note 2 to the financial statements of Southern Power under “FERC Matters — Market-Based Rate Authority” in Item 8 of the Form 10-K for information on the FERC’s April 2004 order adopting a new interim analysis for measuring generation market power and a proceeding initiated by the FERC in December 2004 to assess Southern Company’s generation dominance within its retail service territory. Each of the retail operating companies and Southern Power has authorization from the FERC to sell power to non-affiliates at market-based prices. Through SCS, as agent, 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. On February 15, 2005, Southern Company submitted additional information related to generation dominance in its retail service territory. A hearing before an administrative law judge scheduled for March 2006 has been held in abeyance to allow the parties to explore settlement. Any new market-based rate transactions in Southern Company’s 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. The impact of all such sales through March 31, 2006 is not expected to exceed $19 million for the Southern Company system. The refund period covers 15 months. In the event that the FERC’s default mitigation measures for entities that are found to have market power are ultimately applied, the retail operating companies and Southern Power 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 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.

     In addition, in May 2005, the FERC initiated an investigation to determine whether Southern Company satisfies the other three parts of the FERC’s market-based rate analysis: transmission market power, barriers to entry, and affiliate abuse or reciprocal dealing. The FERC established a new 15-month refund period related to this expanded investigation. Any new market-based rate transactions involving any Southern Company subsidiary will be subject to refund to the extent the FERC orders lower rates as a result of this new investigation, with the refund period beginning July 19, 2005. The impact of all such sales through March 31, 2006 is not expected to exceed $36.8 million, of which $14.8 million relates to sales inside the retail service territory discussed above. The FERC also directed that this expanded proceeding be held in abeyance pending the outcome of the proceeding on the IIC discussed below.

     Southern Company and its subsidiaries believe that there is no meritorious basis for this proceeding and are vigorously defending themselves in this matter. However, the final outcome of this matter, including any remedies to be applied in the event of an adverse ruling in this proceeding, cannot now be determined.

     Also in May 2005, the FERC initiated a new proceeding to examine (1) the provisions of the IIC among Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, Southern Power, and SCS, as agent, under the terms of which the power pool of Southern Company is operated, and, in particular, the propriety of the continued inclusion of Southern Power as a party to the IIC, (2) whether any parties to the IIC have violated the FERC’s standards of conduct applicable to utility companies that are transmission providers, and (3) whether Southern Company’s code of conduct

115

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

defining Southern Power as a “system company” rather than a “marketing affiliate” is just and reasonable. In connection with the formation of Southern Power, the FERC authorized Southern Power’s inclusion in the IIC in 2000. The FERC also previously approved Southern Company’s code of conduct. The FERC order directs that the administrative law judge who presided over a proceeding involving approval of PPAs between Southern Power and Georgia Power and Savannah Electric be assigned to preside over the hearing in this proceeding and that the testimony and exhibits presented in that proceeding be preserved to the extent appropriate. Effective July 19, 2005, revenues from transactions under the IIC involving any Southern Company subsidiaries will be subject to refund to the extent the FERC orders any changes to the IIC. On April 11, 2006, Southern Company, Calpine Corporation, Coral Energy, and Dalton Utilities filed a settlement offer that would resolve the proceeding. The offer is pending before the FERC and does not require any refunds. However, because the offer is pending, the final outcome of this matter cannot now be determined.See Note 3 to the financial statements of Southern Company, Alabama Power, Georgia Power, Gulf Power, Mississippi Power, and Savannah Electric under “FERC Matters — Intercompany Interchange Contract” and Note 2 to the financial statements of Southern Power under “FERC Matters — Intercompany Interchange Contract” in Item 8 of the Form 10-K for additional information.

INCOME TAX MATTERS

See Note 3 to the financial statements of Southern Company under “Income Tax Matters” in Item 8 of the Form 10-K. The IRS challenged Southern Company’s deductions related to three international lease transactions (so-called SILO or sale-in-lease-out transactions), in connection with its audit of Southern Company’s 2000 and 2001 tax returns. If the IRS is ultimately successful in disallowing the tax deductions related to these transactions beginning with the 2000 tax year, Southern Company could be subject to additional interest charges of up to $39 million. The IRS had initially proposed a penalty of approximately $16 million, which has now been withdrawn. Additionally, although the payment of the tax liability, exclusive of interest and any penalties, would not affect Southern Company’s results of operations under current accounting standards, it could have a material impact on cash flow. See Note 1 to the financial statements of Southern Company under “Leveraged Leases” in Item 8 of the Form 10-K for additional details of the deferred taxes related to these transactions. Furthermore, the FASB has recently proposed changes to the accounting for both leveraged leases and uncertain tax positions that may be effective beginning in 2007. If approved as proposed, these changes could require Southern Company to reflect the tax deductions that the IRS is challenging as currently payable on the balance sheet and to change the timing of income recognized under the leases, including a cumulative effect upon adoption of the change. For the lease-in-lease-out (LILO) transaction settled with the IRS in February 2005, Southern Company estimates such cumulative effect would reduce Southern Company’s net income by approximately $16 million. The impact of these proposed changes related to the SILO transactions would be dependent on the outcome of pending litigation, but could be significant, and potentially material, to Southern Company’s net income. Southern Company believes these transactions are valid leases for U.S. tax purposes, the related deductions are allowable, and the assessment of a penalty is inappropriate. Southern Company is continuing to pursue resolution of these matters with the IRS; however, the ultimate outcome of these matters cannot now be determined.

SOUTHERN COMPANY GAS SALE

On January 4, 2006 Southern Company completed the sale of substantially all the assets of Southern Company Gas, its competitive retail natural gas marketing subsidiary, including natural gas inventory, accounts receivable, and customer list, to Gas South, LLC, an affiliate of Cobb Electric Membership Corporation. Southern Company Gas’ sale of such assets was pursuant to a Purchase and Sale Agreement dated November 18, 2005 between Southern Company Gas and Gas South. The gross proceeds from the sale were approximately $131 million. This sale had no material impact on Southern Company’s net income for the quarter ending March 31, 2006. As a result of the sale, Southern Company’s financial statements and related information reflect Southern Company Gas as discontinued operations.

116

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

	GEORGIA POWER FAIR LABOR STANDARDS ACT LITIGATION
	On February 23, 2006, approximately 170 current and former employees of Georgia Power filed a collective action against Georgia Power in the U.S. District Court for the Northern District of Georgia, alleging that Georgia Power violated the Fair Labor Standards Act by failing to properly compensate certain employees (primarily linemen and crew leaders whose work is governed by a union collective bargaining agreement) while the employees were subject to being called back into work under on-call work rules and regulations. The plaintiffs are seeking overtime compensation for on-call time for the three-year period prior to the filing of the action, liquidated damages in an amount equal to unpaid overtime compensation they say they have been denied, declaratory and injunctive relief, and attorney’s fees and expenses of litigation. Georgia Power believes that it has complied with the provisions of the Fair Labor Standards Act and it intends to vigorously defend this action. The ultimate outcome of this matter cannot now be determined; however, an adverse outcome could result in the payment of substantial damages.
(C)	See Note 1 to the financial statements of Southern Company and the retail operating companies under “Stock Options” and Note 8 to the financial statements of Southern Company and the retail operating companies under “Stock Option Plan” in Item 8 of the Form 10-K for information regarding non-qualified employee stock options provided by Southern Company. Southern Company and the retail operating companies have not modified any of their stock option plans or outstanding stock options, nor have they changed the underlying valuation assumptions used in valuing the stock options. Employee stock options vest proportionately over a three-year service period, which the companies recognize on a straight-line basis. Prior to January 1, 2006, Southern Company accounted for options granted in accordance with Accounting Principles Board Opinion No. 25; thus, no compensation expense was recognized because the exercise price of all options granted equaled the fair market value on the date of the grant.
	Effective January 1, 2006, Southern Company and the retail operating companies adopted the fair value recognition provisions of FASB Statement No. 123(R), using the modified prospective method. Under that method, compensation cost recognized in the three-month period ended March 31, 2006 is recognized as the requisite service is rendered and includes: (a) compensation cost for the portion of share-based awards granted prior to and that are outstanding as at January 1, 2006, for which the requisite service has not been rendered, based on the grant-date fair value of those awards as calculated in accordance with the original provisions of Statement No. 123, and (b) compensation cost for all share-based awards granted subsequent to January 1, 2006, based on the grant-date fair value estimated in accordance with the provisions of Statement No. 123(R). Results for prior periods have not been restated.
	For Southern Company and each of the retail operating companies, the adoption of Statement No. 123(R) has resulted in a reduction in earnings from continuing operations before income taxes, net income, and operating cash flows as follows (in millions):

Three-months ended March 31, 2006	Earnings Before				Operating Cash
	Income Taxes		Net Income		Flows1
Alabama Power	$	3.6	$	2.2	$	0.2
Georgia Power		3.7		2.3		0.4
Gulf Power		0.6		0.4		0.1
Mississippi Power		0.7		0.5		—
Savannah Electric		0.3		0.2		—
Southern Company	$	19.1	$	11.8	$	2.0

¹ Financing cash flows have increased by the stated amount for Southern Company and each retail operating company, respectively.

117

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

Basic and diluted earnings per share from continuing operations for the three-month period ended March 31, 2006 would have been $0.37 and $0.36, respectively, if Southern Company had not adopted Statement No. 123(R), compared to reported basic and diluted earnings per share of $0.35 and $0.35, respectively.

For the periods prior to the adoption of Statement No. 123(R), the pro forma impact of fair-value accounting for options granted on earnings from continuing operations, and basic and diluted earnings per share is as follows:

Three-months ended March 31, 2005			Options
			Impact
	As Reported		After Tax		Pro Forma
Net income after dividends on preferred and preference stock (in millions):
Alabama Power	$	93.4	$	2.2	$	91.2
Georgia Power		142.4		2.4		140.0
Gulf Power		14.6		0.4		14.2
Mississippi Power		16.9		0.5		16.4
Savannah Electric		1.0		0.3		0.7
Southern Company	$	317.5	$	12.0	$	305.5
Earnings per share (Dollars):
Basic	$	0.43			$	0.41
Diluted	$	0.42			$	0.41

The estimated fair values of stock options granted in 2006 and 2005 were derived using the Black-Scholes stock option pricing model. Expected volatility is based on historical volatility of Southern Company’s stock over a period equal to the expected term. Southern Company uses historical exercise data to estimate the expected term that represents the period of time that options granted to employees are expected to be outstanding. The risk-free rate is based on the U.S. Treasury yield curve in effect at the time of grant that covers the expected term of the stock options. The following table shows the assumptions used in the pricing model and the weighted average grant-date fair value of stock options granted:

Period ended March 31	2006			2005
Expected volatility		16.9	%		17.9	%
Expected term (in years)		5.0			5.0
Interest rate		4.6	%		3.9	%
Dividend yield		4.4	%		4.4	%
Weighted average grant-date fair value	$	4.15		$	3.90

Southern Company and each of the retail operating companies’ activity under the stock option plan as of March 31, 2006, and changes during the quarter then ended, is summarized below:

Shares Subject to	Southern			Alabama			Georgia			Gulf			Mississippi			Savannah
Option	Company			Power			Power			Power			Power			Electric
Outstanding at December 31, 2005		31,347,355			5,227,985			6,705,891			1,099,549			1,444,438			517,984
Granted		6,618,159			1,145,964			1,335,947			240,162			253,256			88,816
Exercised		(600,789	)		(95,921	)		(122,310	)		(32,344	)		(2,458	)		(6,340	)
Canceled		(111,106	)		(2,566	)		(1,428	)		—			—			—
Outstanding at March 31, 2006		37,253,619			6,275,462			7,918,100			1,307,367			1,695,236			600,460
Exercisable at March 31, 2006		24,103,880			3,977,722			5,265,070			829,763			1,178,146			392,147

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

The number of stock options vested and expected to vest at March 31, 2006 is not significantly different from the number of stock options outstanding as detailed above.

Weighted-Average Exercise	Southern		Alabama		Georgia		Gulf		Mississippi		Savannah
Price	Company		Power		Power		Power		Power		Electric
Outstanding at December 31, 2005	$	27.13	$	27.09	$	26.82	$	27.07	$	26.86	$	27.53
Granted		33.81		33.81		33.81		33.81		33.81		33.81
Exercised		22.77		23.92		22.79		21.76		20.81		22.36
Canceled		31.12		25.28		31.37		—		—		—
Outstanding at March 31, 2006	$	28.38	$	28.37	$	28.06	$	28.44	$	27.91	$	28.52
Exercisable at March 31, 2006	$	26.00	$	25.85	$	25.71	$	25.97	$	25.81	$	26.35

At March 31, 2006	Southern		Alabama		Georgia		Gulf		Mississippi		Savannah
(in millions unless stated)	Company		Power		Power		Power		Power		Electric
Weighted-Average Remaining Contractual Term — Outstanding (in years)		7.1		7.4		7.1		7.3		6.7		6.4
Weighted-Average Remaining Contractual Term — Exercisable (in years)		5.9		6.3		6.0		6.2		5.6		5.7
Aggregate Intrinsic Value — Outstanding	$	210.4	$	35.5	$	47.2	$	7.3	$	10.4	$	3.3
Aggregate Intrinsic Value — Exercisable	$	193.4	$	32.5	$	43.8	$	6.7	$	9.7	$	3.0
Three-month period
The total intrinsic value of options exercised during 2006	$	7.1	$	0.8	$	1.6	$	0.4		—	$	0.1
The total intrinsic value of options exercised during 2005	$	40.8	$	6.9	$	6.8	$	0.7	$	1.9	$	0.8

	Southern Company’s total pre-tax compensation cost related to non-vested awards not yet recognized is expected to be approximately $18 million over the remaining three-year service period.
	Southern Company has a policy of issuing shares to satisfy share option exercises. This has been satisfied by the issuance of new common shares; however, during January 2006 Southern Company started reissuing treasury shares that it had previously repurchased. Cash received from issuances related to option exercise under the share-based payment arrangements for the three-month periods ended March 31, 2006 and 2005 was $13.6 million, and $55.2 million, respectively.
(D)	See Note 1 to the financial statements of Southern Company, Alabama Power, Georgia Power, Gulf Power, Mississippi Power, and Savannah Electric under “Asset Retirement Obligations and Other Costs of Removal” in Item 8 of the Form 10-K. The following table reflects the details of the asset retirement obligations included in the Condensed Balance Sheets (in millions).

	Balance at		Liabilities		Liabilities					Cash Flow			Balance at
	12/31/05		Incurred		Settled			Accretion		Revisions			3/31/06
Alabama Power	$	446.3	$	—	$	(0.1	)	$	7.3	$	—		$	453.5
Georgia Power		627.5		—		(0.2	)		9.9		—			637.2
Gulf Power		15.3		—		—			0.2		—			15.5
Mississippi Power		15.4		—		—			0.3		(0.2	)		15.5
Savannah Electric		7.5		—		—			0.1		—			7.6
Southern Company	$	1,117.3	$	—	$	(0.3	)	$	17.9	$	(0.2	)	$	1,134.7

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

(E) For Southern Company, the only difference in computing basic and diluted earnings per share is attributable to exercised options and outstanding options under the stock option plan. See Note 8 to the financial statements of Southern Company in Item 8 of the Form 10-K for further information on the stock option plan. The effect of the stock options was determined using the treasury stock method. Shares used to compute diluted earnings per share are as follows (in thousands):

	Three Months Ended		Three Months Ended
	March 31, 2006		March 31, 2005
As reported shares		742,195		744,025
Effect of options		4,844		4,647
Diluted shares		747,039		748,672

(F) See Note 6 to the financial statements of Southern Company, Alabama Power, Georgia Power, Gulf Power, Mississippi Power, Savannah Electric, and Note 5 to the financial statements of Southern Power under “Financial Instruments” in Item 8 of the Form 10-K. At March 31, 2006, the fair value gains/(losses) of derivative energy contracts was reflected in the financial statements as follows (in millions):

	Southern			Alabama			Georgia			Gulf			Mississippi		Savannah		Southern
	Company			Power			Power			Power			Power		Electric		Power
Regulatory (assets)/liabilities, net	$	(35.3	)	$	(22.5	)	$	(20.2	)	$	(3.3	)	$	9.9	$	0.9	$	—
Accumulated other comprehensive income (loss)		(0.1	)		—			—			—			—		—		(0.1	)
Net income (loss)		0.4			—			—			—			—		—		2.3
Total fair value gain/(loss)	$	(35.0	)	$	(22.5	)	$	(20.2	)	$	(3.3	)	$	9.9	$	0.9	$	2.2

For the three months ended March 31, 2006, the unrealized gain recognized in income for derivative energy contracts that are not hedges was $2.2 million for Southern Power and was immaterial for the other registrants, and for the three months ended March 31, 2005, the amounts were immaterial for all registrants.

The amounts expected to be reclassified from other comprehensive income to fuel expense for the twelve-month period ending March 31, 2006 were immaterial for each registrant. Additionally, no material ineffectiveness has been recorded in net income for the three months ended March 31, 2006 and 2005.

At March 31, 2006, Southern Company had $2.6 billion notional amount of interest rate derivatives outstanding with net fair value gains of $25.9 million as follows:

Fair Value Hedges

					Fair Value Gain
				Hedge	(Loss)
	Notional	Fixed Rate	Variable	Maturity	March 31, 2006
	Amount	Received	Rate Paid	Date	(in millions)
Southern Company	$400 million	5.30%	6-month LIBOR (in arrears) less 0.103%	February 2007	$	0.3

120

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

Cash Flow Hedges

					Fair Value
			Weighted Average	Hedge	Gain (Loss)
	Notional	Variable Rate	Fixed Rate	Maturity	March 31, 2006
	Amount	Received	Paid	Date	(in millions)
Alabama Power	$536 million	BMA Index	2.01%	January 2007	$	7.2
Alabama Power	$195 million	3-month LIBOR	1.89%	April 2006		1.3
Georgia Power*	$300 million	3-month LIBOR	5.75%	July 2037		7.3
Georgia Power**	$400 million	Floating	3.20–3.85%	December 2007		1.3
Georgia Power	$225 million	3-month LIBOR	5.29%	March 2017		2.1
Georgia Power	$150 million	3-month LIBOR	5.30%	December 2016		1.3
Georgia Power	$300 million	1-month LIBOR	2.68%	June 2007		3.2
Savannah Electric	$14 million	BMA Index	2.50%	December 2007		0.3
Savannah Electric	$30 million	3-month LIBOR	4.69%	May 2016		1.6

*	Interest rate collar (showing rate cap percentage)
**	Series of interest rate collars with variable rate based on one-month LIBOR (showing range of rate cap percentage)

For the next twelve month period ending March 31, 2007, the following table reflects the estimated pre-tax gains/(losses) that will be reclassified from Accumulated Other Comprehensive Income to Interest Expense.

	(in millions)
Alabama Power	$	8.8
Georgia Power		1.5
Gulf Power		(0.3	)
Savannah Electric		0.3
Southern Power		(12.1	)
Southern Company	$	(1.8	)

(G) See Note 2 to the financial statements of Southern Company, Alabama Power, Georgia Power, Gulf Power, Mississippi Power, and Savannah Electric in Item 8 of the Form 10-K. Components of the pension plans’ and postretirement plans’ net periodic costs for the three-month periods ending March 31, 2006 and 2005 are as follows (in millions):

	Southern			Alabama			Georgia			Gulf			Mississippi			Savannah
PENSION PLANS	Company			Power			Power			Power			Power			Electric
Three Months Ended March 31, 2006
Service cost	$	38		$	9		$	12		$	2		$	2		$	1
Interest cost		75			19			28			3			3			2
Expected return on plan assets		(114	)		(35	)		(45	)		(5	)		(4	)		(1	)
Recognized net (gain)/loss		4			1			1			—			—			—
Net amortization		7			2			2			—			—			—
Net cost (income)	$	10		$	(4	)	$	(2	)	$	—		$	1		$	2

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

Three Months Ended March 31, 2005
Service cost	$	36		$	8		$	11		$	2		$	2		$	1
Interest cost		72			19			27			3			3			1
Expected return on plan assets		(116	)		(35	)		(46	)		(5	)		(5	)		(1	)
Recognized net (gain)/loss		3			1			1			—			—			—
Net amortization		5			2			2			—			—			—
Net cost (income)	$	—		$	(5	)	$	(5	)	$	—		$	—		$	1

POSTRETIREMENT PLANS	Southern			Alabama			Georgia			Gulf		Mississippi		Savannah
	Company			Power			Power			Power		Power		Electric
Three Months Ended March 31, 2006
Service cost	$	7		$	2		$	3		$	—	$	—	$	—
Interest cost		25			6			10			1		1		1
Expected return on plan assets		(12	)		(4	)		(6	)		—		—		—
Net amortization		11			3			5			—		—		—
Net cost (income)	$	31		$	7		$	12		$	1	$	1	$	1
Three Months Ended March 31, 2005
Service cost	$	7		$	2		$	3		$	—	$	—	$	—
Interest cost		24			7			10			1		1		1
Expected return on plan assets		(11	)		(4	)		(6	)		—		—		—
Net amortization		9			2			5			—		—		—
Net cost (income)	$	29		$	7		$	12		$	1	$	1	$	1

(H)	See Note 3 to the financial statements of Georgia Power and Savannah Electric under “Merger” and “Fuel Cost Recovery,” respectively, in Item 8 of the Form 10-K for information on the proposed merger of Savannah Electric into Georgia Power and its impact on retail fuel cost recovery. As of the end of March 2006, Savannah Electric had an under recovered fuel balance of $81 million, and Georgia Power had an under recovered fuel balance of about $784 million, including approximately $392 million related to fuel used since June 2005. In March 2006, Georgia Power and Savannah Electric filed a combined request with the Georgia PSC to change the fuel cost recovery rate.
	The case seeks approval of a fuel cost recovery rate based upon future fuel cost projections for the combined Georgia Power and Savannah Electric generating fleet as well as the under recovered balances existing at June 30, 2006. The new fuel cost recovery rate would be billed beginning in July 2006 to all Georgia Power customers, including the existing Savannah Electric customers, pending completion of the merger. Under recovered amounts as of the date of the merger will be paid by the appropriate customer groups. The proposed fuel rates are based on an amortization period of 35 months for Georgia Power customers and 41 months for former Savannah Electric territory customers.
	Fuel cost recovery revenues as recorded on the financial statements are adjusted for differences in actual recoverable costs and amounts billed in current regulated rates. Accordingly, any increase in the billing factor will have no significant effect on Georgia Power’s revenues or net income, but will increase cash flow.
(I)	See Note 1 to the financial statements of Southern Company and Mississippi Power under “Storm Damage Reserves” and “Provision for Property Damage,” respectively, in Item 8 of the Form 10-K for information on how Mississippi Power maintains a reserve for property damage to cover the cost of damages from major storms to its transmission and distribution lines and the cost of uninsured damages to its generation facilities and other property. Hurricane Katrina hit the coast of Florida, Alabama, Mississippi, and Louisiana on August 29, 2005, causing substantial damage. Prior to Hurricane Katrina, Mississippi Power had a balance of approximately $3 million in its property reserve. In October 2005, the Mississippi PSC issued an Interim Accounting Order requiring Mississippi Power to recognize a regulatory asset in an amount equal to the retail portion of the recorded Hurricane Katrina restoration costs, including both operation and maintenance expenditures and capital additions. The balance in the regulatory asset account at March 31, 2006 is $234.5 million, which is net of insurance proceeds of $76.4 million. These costs include approximately $164.4 million of capital additions and $151.5 million of operation and maintenance expenditures.

122

NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

	In December 2005, Mississippi Power filed with the Mississippi PSC a detailed review of all Hurricane Katrina restoration costs as required in the Interim Accounting Order. Mississippi Power is currently working with the Mississippi PSC to establish a method to recover all such prudently incurred costs, while minimizing the impact on Mississippi Power’s customers. The Department of Defense emergency supplemental appropriations bill, enacted in December 2005 to address restoration efforts related to hurricanes in the Gulf of Mexico, provides $11 billion in disaster relief for the States of Mississippi, Louisiana, and Alabama. In the State of Mississippi, $300 million in grant assistance in the form of Community Development Block Grants (CDBGs) is expected to be designated for utilities within the state. Mississippi Power will apply for these CDBGs to offset the cost of storm recovery. Mississippi Power is also considering securitization of remaining unrecovered costs as provided for under legislation passed in the State of Mississippi in the first quarter of 2006.
	In December 2005, Mississippi Power submitted its annual PEP filing to the Mississippi PSC. Ordinarily, PEP limits annual rate increases to 4%; however, Mississippi Power requested that the Mississippi PSC approve a temporary change to allow it to exceed this cap as a result of the ongoing effects of Hurricane Katrina. Mississippi Power had requested a 5.05%, or $32 million, retail base rate increase to become effective in April 2006. Hearings were held in March 2006 and the full increase was approved by the Mississippi PSC on March 13, 2006. See Note 3 to the financial statements of Southern Company and Mississippi Power under “PSC Matters — Mississippi Power” and “Retail Regulatory Matters — Performance Evaluation Plan” respectively, in Item 8 of the Form 10-K for additional information.
	On February 7, 2006, Mississippi Power filed with the Mississippi PSC its annual ECO Plan evaluation. Mississippi Power requested a 12 cent per 1,000 KWH reduction for retail customers. The decrease represents a reduction of approximately $1.3 million per year in annual revenues for Mississippi Power. Hearings were held on April 4, 2006. The Mississippi PSC unanimously approved the decrease at the hearings and issued an order confirming approval on April 21, 2006.
(J)	See Note 5 to the financial statements of Southern Company, Alabama Power, and Savannah Electric in Item 8 of the Form 10-K for information on each company’s effective income tax rate. In accordance with an Alabama PSC-approved accounting order to restore the natural disaster reserve, Alabama Power returned approximately $27.7 million of excess deferred income taxes to its retail customers in 2005. The impact of this entry was a significant reduction in the effective income tax rate for the first quarter of 2005 when compared to the first quarter of 2006 for Alabama Power and Southern Company. For additional information on Alabama Power’s accounting order, see Note 3 to the financial statements of Southern Company and Alabama Power under “Storm Damage Recovery” and “Natural Disaster Cost Recovery,” respectively, in Item 8 of the Form 10-K.
	In connection with construction on the Plant McIntosh combined cycle units, Savannah Electric recorded a decrease in its income tax expense of $1.0 million in 2005 related to AFUDC equity, which is not taxable. In the first quarter of 2006, Savannah Electric recorded a tax benefit of $0.04 million. Tax expense decreased due to the accounting for several items that are not taxable. The impact of these non-taxable items in the first quarter of 2006 and the AFUDC in the first quarter of 2005 caused a significant

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NOTES TO THE CONDENSED FINANCIAL STATEMENTS: (Continued)

	reduction in the effective income tax rate for both quarters for Savannah Electric. For additional information on the Plant McIntosh construction, see Note 3 to the financial statements of Savannah Electric under “Plant McIntosh Construction Project” in Item 8 of the Form 10-K.
	Southern Company recorded reserves associated with a potential phase out of its synthetic fuel tax credits of $18.6 million for the three months ended March 31, 2006. The impact of these reserves caused an increase in the effective tax rate in the first quarter of 2006 compared to the same period in 2005 for Southern Company.
(K)	Southern Company’s reportable business segment is the sale of electricity in the Southeast by the five retail operating companies and Southern Power. Net income and total assets for discontinued operations are included in the “Reconciling Eliminations” column. The “All Other” column includes parent Southern Company, which does not allocate operating expenses to business segments. Also, this category includes segments below the quantitative threshold for separate disclosure. These segments include investments in synthetic fuels and leveraged lease projects, telecommunications, and energy-related services. Southern Power’s revenues from sales to the retail operating companies were $87 million and $112 million for the three months ended March 31, 2006 and for the three months ended March 31, 2005, respectively. All other intersegment revenues are not material. Financial data for business segments and products and services are as follows:

	Electric Utilities
	Retail
	Operating		Southern							All		Reconciling
	Companies		Power		Eliminations			Total		Other		Eliminations			Consolidated
	(in millions)
Three Months Ended March 31, 2006:
Operating revenues	$	2,964	$	140	$	(107	)	$	2,997	$	104	$	(38	)	$	3,063
Segment net income (loss)		239		20		—			259		1		2			262
Total assets at March 31, 2006	$	36,492	$	2,241	$	(88	)	$	38,645	$	1,789		(457	)	$	39,977
Three Months Ended March 31, 2005:
Operating revenues	$	2,697	$	153	$	(133	)	$	2,717	$	96	$	(26	)	$	2,787
Segment net income (loss)		266		23		—			289		30		4			323
Total assets at December 31, 2005	$	36,335	$	2,303	$	(179	)	$	38,459	$	1,751		(333	)	$	39,877

Products and Services

	Electric Utilities Revenues
Period	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2006	$	2,471	$	415	$	111	$	2,997
Three Months Ended March 31, 2005		2,269		347		101		2,717

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  PART II —  OTHER INFORMATION

Item 1.   Legal Proceedings.

See the Notes to the Condensed Financial Statements herein for information regarding certain legal and administrative proceedings in which Southern Company and its reporting subsidiaries are involved.

Item 1A. Risk Factors.

See Item 1A. RISK FACTORS in Part I of the Form 10-K for the year ended December 31, 2005 for a discussion of the risk factors of the Southern Company and the subsidiary registrants. For the quarter ended March 31, 2006, there have been no material changes to these risk factors.

Item 2.   Unregistered Sales of Equity Securities and Use of Proceeds

				Maximum Approximate
			Total Number of	Dollar Value of
			Shares Purchased as	Shares that May Yet
	Total Number of		Part of Publicly	Be Purchased Under
	Shares	Average Price	Announced Plans or	the Plans or
2006	Purchased (a)	Paid Per Share	Programs	Programs (a)
January 1 - January 31	3,363	$34.82	3,363	N/A
February 1 - February 28	—	—	—	N/A
March 1 - March 31	—	—	—	N/A
Total	3,363	$34.82	3,363	N/A

(a) In fiscal year 2004, Southern Company announced that it planned to engage an agent in fiscal year 2005 to repurchase shares of its common stock to offset shares issued in connection with the exercise of stock options under the Southern Omnibus Incentive Compensation Plan (Omnibus Plan). In May 2005, Southern Company engaged an agent to (i) begin repurchasing shares of Southern Company common stock to offset the 6,273,876 shares of common stock issued from January 2005 through May 2005 in connection with the exercise of stock options under the Omnibus Plan and (ii) repurchase shares of Southern Company common stock on an ongoing basis to offset additional shares issued in connection with the exercise of stock options under the Omnibus Plan. As of March 31, 2006, Southern Company has repurchased a total of 10,070,321 shares. In January 2006, Southern Company’s program to repurchase shares of stock to offset issuances under the Southern Company’s stock compensation plans was discontinued.

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Item 6. Exhibits.

(3) Articles of Incorporation and By-Laws

Alabama Power

(b)1 - Amendment to Charter of Alabama Power dated May 1, 2006.

(4) Instruments Describing Rights of Security Holders, Including Indentures

Alabama Power

(b)1 - Thirty-Fifth Supplemental Indenture to Senior Note Indenture dated as of March 15, 2006, providing for the issuance of the Series II Senior Notes. (Designated in Form 8-K dated March 9, 2006, File No. 1-3164, as Exhibit 4.2.)

(10) Material Contracts

Southern Company

(a)1	-	Second Amendment effective March 1, 2006 to The Southern Company Deferred Compensation Plan.
(a)2	-	First Amendment effective March 1, 2006 to The Southern Company Supplemental Executive Retirement Plan.
(a)3	-	Second Amendment effective March 1, 2006 to The Southern Company Supplemental Benefit Plan.

Alabama Power

(b)1	-	Second Amendment effective March 1, 2006 to The Southern Company Deferred Compensation Plan. See Exhibit 10(a)1 herein.
(b)2	-	First Amendment effective March 1, 2006 to The Southern Company Supplemental Executive Retirement Plan. See Exhibit 10(a)2 herein.
(b)3	-	Second Amendment effective March 1, 2006 to The Southern Company Supplemental Benefit Plan. See Exhibit 10(a)3 herein.

Georgia Power

(c)1	-	Second Amendment effective March 1, 2006 to The Southern Company Deferred Compensation Plan. See Exhibit 10(a)1 herein.
(c)2	-	First Amendment effective March 1, 2006 to The Southern Company Supplemental Executive Retirement Plan. See Exhibit 10(a)2 herein.
(c)3	-	Second Amendment effective March 1, 2006 to The Southern Company Supplemental Benefit Plan. See Exhibit 10(a)3 herein.

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Item 6. Exhibits. (continued)

Gulf Power

(d)1	-	Second Amendment effective March 1, 2006 to The Southern Company Deferred Compensation Plan. See Exhibit 10(a)1 herein.
(d)2	-	First Amendment effective March 1, 2006 to The Southern Company Supplemental Executive Retirement Plan. See Exhibit 10(a)2 herein.
(d)3	-	Second Amendment effective March 1, 2006 to The Southern Company Supplemental Benefit Plan. See Exhibit 10(a)3 herein.

Mississippi Power

(e)1	-	Second Amendment effective March 1, 2006 to The Southern Company Deferred Compensation Plan. See Exhibit 10(a)1 herein.
(e)2	-	First Amendment effective March 1, 2006 to The Southern Company Supplemental Executive Retirement Plan. See Exhibit 10(a)2 herein.
(e)3	-	Second Amendment effective March 1, 2006 to The Southern Company Supplemental Benefit Plan. See Exhibit 10(a)3 herein.

Savannah Electric

(f)1	-	Second Amendment effective March 1, 2006 to The Southern Company Deferred Compensation Plan. See Exhibit 10(a)1 herein.
(f)2	-	First Amendment effective March 1, 2006 to The Southern Company Supplemental Executive Retirement Plan. See Exhibit 10(a)2 herein.
(f)3	-	Second Amendment effective March 1, 2006 to The Southern Company Supplemental Benefit Plan. See Exhibit 10(a)3 herein.

(24) Power of Attorney and Resolutions

Southern Company

(a)1 - Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2005, File No. 1-3526 as Exhibit 24(a) and incorporated herein by reference.)

Alabama Power

(b)1 - Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2005, File No. 1-3164 as Exhibit 24(b) and incorporated herein by reference.)

Georgia Power

(c)1 - Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2005, File No. 1-6468 as Exhibit 24(c) and incorporated herein by reference.)

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Item 6. Exhibits. (continued)

Gulf Power

(d)1 - Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2005, File No. 0-2429 as Exhibit 24(d) and incorporated herein by reference.)

Mississippi Power

(e)1 - Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2005, File No. 001-11229 as Exhibit 24(e) and incorporated herein by reference.)

Savannah Electric

(f)1 - Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2005, File No. 1-5072 as Exhibit 24(f) and incorporated herein by reference.)

Southern Power

(g)1 - Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2005, File No. 333-98553 as Exhibit 24(g) and incorporated herein by reference.)

(31) Section 302 Certifications

Southern Company

(a)1	-	Certificate of Southern Company’s Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
(a)2	-	Certificate of Southern Company’s Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Alabama Power

(b)1	-	Certificate of Alabama Power’s Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
(b)2	-	Certificate of Alabama Power’s Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Georgia Power

(c)1	-	Certificate of Georgia Power’s Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
(c)2	-	Certificate of Georgia Power’s Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Gulf Power

(d)1 - Certificate of Gulf Power’s Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

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Item 6. Exhibits. (continued)

(d)2 - Certificate of Gulf Power’s Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Mississippi Power

(e)1	-	Certificate of Mississippi Power’s Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
(e)2	-	Certificate of Mississippi Power’s Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Savannah Electric

(f)1	-	Certificate of Savannah Electric’s Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
(f)2	-	Certificate of Savannah Electric’s Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

Southern Power

(g)1	-	Certificate of Southern Power’s Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
(g)2	-	Certificate of Southern Power’s Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

(32) Section 906 Certifications

Southern Company

(a) - Certificate of Southern Company’s Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Alabama Power

(b) - Certificate of Alabama Power’s Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Georgia Power

(c) - Certificate of Georgia Power’s Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Gulf Power

(d) - Certificate of Gulf Power’s Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

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Item 6. Exhibits. (continued)

Mississippi Power

(e) - Certificate of Mississippi Power’s Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Savannah Electric

(f) - Certificate of Savannah Electric’s Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

Southern Power

(g) - Certificate of Southern Power’s Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.

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THE SOUTHERN COMPANY

SIGNATURES

     Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

	THE SOUTHERN COMPANY
By	David M. Ratcliffe
	Chairman, President and Chief Executive Officer (Principal Executive Officer)
By	Thomas A. Fanning
	Executive Vice President, Chief Financial Officer and Treasurer (Principal Financial Officer)
By	/s/ Wayne Boston
	(Wayne Boston, Attorney-in-fact)

Date: May 4, 2006

131

ALABAMA POWER COMPANY

SIGNATURES

     Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

	ALABAMA POWER COMPANY
By	Charles D. McCrary
	President and Chief Executive Officer (Principal Executive Officer)
By	Art P. Beattie
	Executive Vice President, Chief Financial Officer and Treasurer (Principal Financial Officer)
By	/s/ Wayne Boston
	(Wayne Boston, Attorney-in-fact)

Date: May 4, 2006

132

GEORGIA POWER COMPANY

SIGNATURES

     Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

	GEORGIA POWER COMPANY
By	Michael D. Garrett
	President and Chief Executive Officer (Principal Executive Officer)
By	Cliff S. Thrasher
	Executive Vice President, Chief Financial Officer and Treasurer (Principal Financial Officer)
By	/s/ Wayne Boston
	(Wayne Boston, Attorney-in-fact)

Date: May 4, 2006

133

GULF POWER COMPANY

SIGNATURES

     Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

	GULF POWER COMPANY
By	Susan N. Story
	President and Chief Executive Officer (Principal Executive Officer)
By	Ronnie R. Labrato
	Vice President and Chief Financial Officer (Principal Financial Officer)
By	/s/ Wayne Boston
	(Wayne Boston, Attorney-in-fact)

Date: May 4, 2006

134

MISSISSIPPI POWER COMPANY

SIGNATURES

     Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

	MISSISSIPPI POWER COMPANY
By	Anthony J. Topazi
	President and Chief Executive Officer (Principal Executive Officer)
By	Frances V. Turnage
	Vice President, Treasurer and Chief Financial Officer (Principal Financial Officer)
By	/s/ Wayne Boston
	(Wayne Boston, Attorney-in-fact)

Date: May 4, 2006

135

SAVANNAH ELECTRIC AND POWER COMPANY

SIGNATURES

     Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

	SAVANNAH ELECTRIC AND POWER COMPANY
By	W. Craig Barrs
	President and Chief Executive Officer (Principal Executive Officer)
By	Kirby R. Willis
	Vice President, Treasurer, Chief Financial Officer and Assistant Corporate Secretary (Principal Financial and Accounting Officer)
By	/s/ Wayne Boston
	(Wayne Boston, Attorney-in-fact)

Date: May 4, 2006

136

SOUTHERN POWER COMPANY

SIGNATURES

     Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof.

	SOUTHERN POWER COMPANY
By	Ronnie L. Bates
	President and Chief Executive Officer (Principal Executive Officer)
By	Michael W. Southern
	Senior Vice President and Chief Financial Officer (Principal Financial Officer)
By	/s/ Wayne Boston
	(Wayne Boston, Attorney-in-fact)

Date: May 4, 2006

137