Contingencies and Regulatory Matters - Textual (Details) (USD $)	12 Months Ended						3 Months Ended	12 Months Ended		0 Months Ended		1 Months Ended	3 Months Ended					12 Months Ended										12 Months Ended				0 Months Ended						1 Months Ended	12 Months Ended											0 Months Ended	1 Months Ended			0 Months Ended										0 Months Ended	12 Months Ended			0 Months Ended				1 Months Ended	12 Months Ended													0 Months Ended					0 Months Ended			12 Months Ended									0 Months Ended			12 Months Ended						12 Months Ended		1 Months Ended		12 Months Ended						12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2009	Dec. 10, 2013	Jun. 30, 2012	Mar. 31, 2013 Kemper IGCC [Member]	Dec. 31, 2013 Kemper IGCC [Member]	Dec. 31, 2013 Gulf Power and Mississippi Power [Member]	Nov. 21, 2013 Alabama Power [Member]	Aug. 13, 2013 Alabama Power [Member] Provisions	Jul. 31, 2007 Alabama Power [Member]	Sep. 30, 2013 Alabama Power [Member]	Mar. 31, 2013 Alabama Power [Member]	Mar. 31, 2012 Alabama Power [Member]	Dec. 31, 2011 Alabama Power [Member] MW	Sep. 30, 2011 Alabama Power [Member]	Dec. 31, 2013 Alabama Power [Member] MW	Dec. 31, 2012 Alabama Power [Member] Purchased_Power_Agreement MW	Dec. 31, 2011 Alabama Power [Member] MW	Dec. 31, 2010 Alabama Power [Member] Property	Sep. 30, 2012 Alabama Power [Member] MW	Aug. 13, 2013 Alabama Power [Member] Minimum [Member]	Aug. 13, 2013 Alabama Power [Member] Maximum [Member]	Dec. 31, 2013 Alabama Power [Member] Fuel Recovery Clause [Member]	Aug. 13, 2013 Alabama Power [Member] Current Rate Stabilization And Equalization [Member] Minimum [Member]	Aug. 13, 2013 Alabama Power [Member] Current Rate Stabilization And Equalization [Member] Maximum [Member]	Dec. 31, 2013 Southern Power [Member] MW	Dec. 31, 2012 Southern Power [Member]	Dec. 31, 2011 Southern Power [Member]	Jan. 02, 2013 Southern Power [Member]	Dec. 17, 2013 Georgia Power [Member]	Nov. 04, 2013 Georgia Power [Member] Purchased_Power_Agreement Property	Sep. 03, 2013 Georgia Power [Member]	Jul. 11, 2013 Georgia Power [Member]	Apr. 22, 2013 Georgia Power [Member] Purchased_Power_Agreement MW	Jan. 31, 2013 Georgia Power [Member] MW	Jul. 31, 2007 Georgia Power [Member]	Dec. 31, 2013 Georgia Power [Member] Purchased_Power_Agreement MW	Dec. 31, 2012 Georgia Power [Member]	Dec. 31, 2011 Georgia Power [Member]	Dec. 31, 2008 Georgia Power [Member] MW	Oct. 15, 2013 Georgia Power [Member]	Jan. 02, 2013 Georgia Power [Member]	Jun. 01, 2012 Georgia Power [Member]	Apr. 02, 2012 Georgia Power [Member]	Jan. 02, 2012 Georgia Power [Member]	Jun. 01, 2011 Georgia Power [Member]	Jan. 02, 2011 Georgia Power [Member]	Jan. 02, 2014 Georgia Power [Member] Subsequent Event [Member]	Feb. 27, 2014 Georgia Power [Member] Subsequent Event [Member]	Jan. 02, 2014 Georgia Power [Member] Minimum [Member] Subsequent Event [Member]	Jan. 02, 2014 Georgia Power [Member] Maximum [Member] Subsequent Event [Member]	Dec. 17, 2013 Georgia Power [Member] Pending Litigation [Member] Purchased_Power_Agreement	Dec. 31, 2013 Georgia Power [Member] Storm Costs [Member]	Apr. 17, 2013 Georgia Power [Member] Plant Bowen [Member] MW	Sep. 30, 2013 Georgia Power [Member] Plant Branch Unit Two [Member] MW	Jul. 11, 2013 Georgia Power [Member] Plant Boulevard [Member] MW	Jul. 11, 2013 Georgia Power [Member] Plant Branch [Member] MW	Jul. 11, 2013 Georgia Power [Member] Plant Yates [Member] MW	Jul. 11, 2013 Georgia Power [Member] Plant McManus [Member] MW	Jul. 11, 2013 Georgia Power [Member] Plant Kraft [Member] MW	Jan. 10, 2014 Georgia Power [Member] Plant Mitchell [Member] Subsequent Event [Member] MW	Dec. 17, 2013 Georgia Power [Member] Georgia Advanced Solar Initiative [Member] Property MW	Dec. 31, 2009 Georgia Power [Member] Plant Vogtle Units 3 And 4 [Member]	Dec. 31, 2013 Georgia Power [Member] Utility Scale Projects [Member] MW	Dec. 31, 2013 Georgia Power [Member] Electric Distribution [Member] MW	Jul. 11, 2013 Mississippi Power [Member] Customer	Apr. 02, 2013 Mississippi Power [Member]	Mar. 19, 2013 Mississippi Power [Member]	Apr. 02, 2012 Mississippi Power [Member]	Jun. 30, 2012 Mississippi Power [Member]	Dec. 31, 2013 Mississippi Power [Member] MW mi	Dec. 31, 2012 Mississippi Power [Member]	Dec. 31, 2011 Mississippi Power [Member]	Jun. 04, 2013 Mississippi Power [Member]	Mar. 22, 2013 Mississippi Power [Member]	Mar. 15, 2013 Mississippi Power [Member]	Mar. 05, 2013 Mississippi Power [Member]	Apr. 30, 2012 Mississippi Power [Member]	Mar. 31, 2012 Mississippi Power [Member]	Feb. 28, 2012 Mississippi Power [Member]	Nov. 30, 2011 Mississippi Power [Member]	Jun. 30, 2011 Mississippi Power [Member]	Dec. 31, 2010 Mississippi Power [Member]	Jan. 02, 2014 Mississippi Power [Member] Subsequent Event [Member]	Feb. 27, 2014 Mississippi Power [Member] Subsequent Event [Member]	Feb. 03, 2014 Mississippi Power [Member] Subsequent Event [Member]	Feb. 02, 2014 Mississippi Power [Member] Subsequent Event [Member]	Dec. 31, 2013 Mississippi Power [Member] Plant Daniel Units 1 and 2 [Member]	Jul. 11, 2013 Mississippi Power [Member] Minimum [Member]	Jul. 11, 2013 Mississippi Power [Member] Maximum [Member]	Jan. 25, 2013 Mississippi Power [Member] Maximum [Member]	Dec. 31, 2013 Mississippi Power [Member] Retail [Member]	Dec. 31, 2013 Mississippi Power [Member] MRA Revenue [Member]	Dec. 31, 2012 Mississippi Power [Member] MRA Revenue [Member]	Dec. 31, 2013 Mississippi Power [Member] MB Revenue [Member]	Dec. 31, 2012 Mississippi Power [Member] MB Revenue [Member]	Dec. 31, 2013 Mississippi Power [Member] Hurricane [Member]	Dec. 31, 2012 Mississippi Power [Member] Hurricane [Member]	Dec. 31, 2013 Mississippi Power [Member] Gulf Power [Member]	Dec. 31, 2013 Mississippi Power [Member] Gulf Power [Member] Plant Daniel Units 1 and 2 [Member] MW	Mar. 22, 2013 Mississippi Power [Member] Electricity Generation Plant, Non-Nuclear [Member]	Feb. 26, 2013 Mississippi Power [Member] Electricity Generation Plant, Non-Nuclear [Member]	Jan. 24, 2013 Mississippi Power [Member] Electricity Generation Plant, Non-Nuclear [Member]	Dec. 31, 2013 Mississippi Power [Member] Kemper IGCC [Member]		Dec. 31, 2012 Mississippi Power [Member] Kemper IGCC [Member]	Mar. 29, 2013 Mississippi Power [Member] Kemper IGCC [Member] MW	Jan. 02, 2013 Mississippi Power [Member] Kemper IGCC [Member] Minimum [Member]	Jan. 02, 2013 Mississippi Power [Member] Kemper IGCC [Member] Maximum [Member]	Dec. 31, 2013 Mississippi Power [Member] Kemper IGCC [Member] Maximum Up To Year Two Thousand Twenty [Member]	Dec. 31, 2010 Mississippi Power [Member] Mine [Member]	Nov. 30, 2011 Mississippi Power [Member] Plant Daniel Units 3 and 4 [Member]	Oct. 20, 2011 Mississippi Power [Member] Plant Daniel Units 3 and 4 [Member]	Dec. 31, 2013 Gulf Power [Member]	Dec. 31, 2012 Gulf Power [Member]	Dec. 31, 2011 Gulf Power [Member]	Dec. 03, 2013 Gulf Power [Member]	Nov. 04, 2013 Gulf Power [Member]	Dec. 31, 2013 Gulf Power [Member] Plant Daniel Units 1 and 2 [Member] MW	Dec. 31, 2013 Gulf Power [Member] Minimum [Member]	Dec. 31, 2013 Gulf Power [Member] Maximum [Member] kWh	Dec. 31, 2013 Under Recovered Regulatory Clause Revenues and Other Current Liabilities [Member] Gulf Power [Member]	Dec. 31, 2013 Other Regulatory Assets, Deferred and Other Deferred Credits and Liabilities [Member] Gulf Power [Member]	Dec. 31, 2013 Other regulatory liabilities current [Member] Gulf Power [Member]	Dec. 31, 2012 Other regulatory liabilities current [Member] Gulf Power [Member]	Dec. 31, 2013 Regulatory Clause Revenues, under-recovered [Member] Gulf Power [Member]	Dec. 31, 2012 Regulatory Clause Revenues, under-recovered [Member] Gulf Power [Member]	Dec. 31, 2013 Prime Rate [Member] Gulf Power [Member]	Dec. 31, 2013 Settlement Agreement [Member] Gulf Power [Member]
Loss Contingencies [Line Items]
Percent Of Designated Customer Value Benchmark Survey													33.30%
Insurance Recovery [Abstract]
Gain (Loss) Related to Litigation Settlement				$ (202,000,000)
Amount of Insurance Claim Received in Respect of Litigation Settlement					15,000,000	25,000,000
Legal Fee Related to Insurance Recoveries	4,000,000	6,000,000
Net Amount Received of Insurance Claim in Respect of Litigation Settlement	11,000,000	19,000,000
Environmental Matters [Abstract]
Civil penalties under Clean Air Act per day, lower range	25,000																	25,000																					25,000																																		25,000																																											25,000
Civil penalties under Clean Air Act per day, upper range	37,500																	37,500																					37,500																																		37,500																																											37,500
Environmental remediation liability																																							18,000,000																																																																													50,400,000								3,100,000	47,300,000
Civil penalties per violation rate																																							37,500
Number of times of punitive damages in comparison to cost incurred by Environmental Protection Agency																																							3
FERC Matters [Abstract]
Increase in Annual Base Wholesale Revenues																																																																							22,600,000												32,000,000
Operating lease, initial term																																																																																																																		10 years
Public Utilities, Property, Plant and Equipment, Generation, Useful Life																																																																																																																		30 years
Period Over Which Annual Revenue Will Increase Under Tariff																																																																							12 months
Increase in Base Rate Under Cost Based Electric Tariff Due to Settlement																																																																					24,200,000
Nuclear Fuel Disposal Costs [Abstract]
Claims awarded to companies related to nuclear fuel disposal litigation												17,000,000																										27,000,000
Retail Regulatory Matters [Abstract]
Portion of Actual Earnings Above Approved ROE Band Retained by Subsidiary Company																																							33.33333%
Portion of Actual Earnings Above Approved ROE Band Refunded to Customers																																							66.66667%
Anticipates of elimination adjustment will result in additional revenues																31,000,000			106,000,000																																																						3,300,000
Annual PEP Lookback Refund To Customers																																																																														4,700,000
Rate Adjustment Period																		2 years
Maximum percentage of Rate RSE																		4.00%
Maximum annual percentage of ratio rate																		5.00%
Minimum projected retail return on common equity at which retail rates remain unchanged																		13.00%
Maximum projected retail return on common equity at which retail rates remain unchanged																		14.50%
Maximum increase in rate RSE																		5.00%
Allowed Equity Ratio											45.00%
Number Of Provisions											2
Weighted Cost Of Equity																							5.75%	6.21%		5.85%	6.53%
Adjusting Point Of Weighted Cost Of Equity											5.98%																6.19%
Period Of Treasury Yield Rate																																																																																																																				30 years
Percent Of Basis Points											0.07%																																																																																																									0.25%						0.75%
Under recovered certified PPA balance																		18,000,000
Approved And Certified Energy From Wind-Powered Generating Facilities																200			200	200		200
Number Of Wind Farms																			2														2
Under Recovered Rate Cnp Balance											58,000,000
Unrecovered Retail Revenue Requirement For Environmental Compliance										72,000,000
Under recovered environmental clause																		7,000,000
Period Which Deferred Regulatory Asset Account, Amortized																		3 years
Period Which Afforded Regulatory Asset Treatment																		5 years
Compliance-related Operation Maintenance Expenditures																		37,000,000
Operation And Maintenance Cost Deferred To Regulatory Asset																		8,000,000
Incremental Increase In Pension Cost																		12,000,000
Approved billing rate under rate ECR up to (cents per KWH)																		0.05910
Future stated rates under rate Ecr factor in terms of per units																		0.02681
Over recovered fuel cost																		42,000,000																																																								56,600,000																				14,500,000	7,300,000	19,000,000	300,000	2,100,000
Amount Of Under Recovered Emissions Allowance Cost																																																																																															3,800,000	400,000
Under recovered fuel cost																			4,000,000
Other Regulatory Liabilities, Current	92,000,000	107,000,000																37,000,000	3,000,000						27,000,000														17,000,000	73,000,000																																	24,981,000	5,376,000																																										13,408,000	25,887,000
Deferred over recovered regulatory clause revenues																		15,000,000	0						15,000,000
Maximum Period for recovery deferred storm-related operations and maintenance costs and any future reserve deficit																		24 months
Maximum total rate NDR charge per month, non-residential customer account																		10
Maximum total rate NDR charge per month, residential customer account																		5
Old Natural Disaster Reserve Authorized Limit																		75,000,000
Accumulated NDR reserve reflected as other regulatory liabilities, deferred																		96,000,000	103,000,000
Number of units for which outage operations and maintenance expenses accrued																					2
Period over which deferred costs are being amortized to nuclear operations and maintenance expenses													18 months	18 months	18 months			18 months			18 months
Nuclear outage expense													32,000,000	28,000,000	31,000,000		38,000,000	31,000,000
Period To Amortize Expense											3 years
Outage Expenditures											78,000,000
Base Rate Increases																																												74,000,000		125,000,000	17,000,000		562,000,000
Number Of Intervenors Approved ARP																																11
Number of Intervenors																																13
Increase in traditional base tariff rates																																																		80,000,000
Estimated Increase In ECCR Tariff																																																		25,000,000
Estimated Demand Side Management Tariffs																																																		1,000,000
Estimated Increase In Demand Side Management Tariffs																																																		6,000,000
Estimated Increase In Municipal Franchise Fee Tariff																																																		4,000,000
Base Revenue under Alternate Base Plan																																																		110,000,000
Period For Levelized Revenue Requirements																																																		90 days
Increase in Tariff Rate Two																																																		101,000,000
Increase in Tariff Rate Three																																																		36,000,000
Estimated Increase In ECCR Tariff One																																																		76,000,000
Estimated Increase In ECCR Tariff Two																																																		131,000,000
Estimated Decrease In Demand Side Management Tariffs																																																		1,000,000
Revenue to be Received from Increase in Base Rate One																																																		187,000,000
Revenue to be Received from Increase in Base Rate																																																		170,000,000
Retail Rate of Return on Common Equity																																																		10.95%		10.00%	12.00%
Test Period For PSC																																																		90 days
Capacity Of Units Included In Request by Subsidiaries For Decertification Of Units																																					2,093
Capacity Of Units Approved For Decertification Of Units																																																								32	319	28	1,016	579	122	316
Extension Period For Mercury And Air Toxics Standards																																			1 year
Period for Environmental Construction																																							9 years											9 years
Capacity Of Small Power Production Facility																																							169																								155
Number Of Wind PPAs																																	2			2			4															2										4
Energy From Solar Generation																																							525																									50		425	100
Number Of Wind PPAs																																				2
Energy From Wind-Powered Generating Facilities																			400																	250
Increase in total annual billing based on fuel cost recovery rate approved by Georgia Power																																												122,000,000	567,000,000			43,000,000
Adjustment To Fuel Cost Recovery Rate If Under Recovered Fuel Balance Exceeds Budget Thereafter																																							200,000,000
Required Period For Options And Hedges																																							24 months
Under recovered fuel balance																																																																																																																																21,000,000
Deferral of maintenance costs																																																							37,000,000
Electric generating capacity in Mega Watts under consortium agreement																																										1,100
Percentage of proportionate share owed in Consortium Agreement																																							45.70%
Number of New Nuclear Generating Units																																																																	2
Increase In NCCR Tariff Year One																																												50,000,000			35,000,000		223,000,000	60,000,000
Amortization to earnings of financing costs capitalized over the five year period																																							91,000,000
Amortization period for financing costs collected																																							5 years
Costs included in CWIP																																							37,000,000																																		2,740,000,000
Increase (Decrease) In Projected Certified Construction Capital Costs																																							5.00%
Estimated In-service Capital Cost																																							4,400,000,000
Amendment To Estimated In-service Capital Cost																																							4,800,000,000
Construction Capital Costs																																		2,400,000,000																	4,800,000,000
Estimated Adjustment to Contract Price Related to Issues that May Impact Project Budget and Schedule																																							425,000,000
Construction And Capital Costs Included In Semi Annual Construction Monitoring Report																																											2,200,000,000								2,000,000,000
Additional Construction Capital Costs																																																			400,000,000
Number of Plants For Decertification																																					16
Over recovered fuel balance																																							58,000,000	230,000,000																																												3,700,000																																											17,100,000
Percent ownership									50.00%									14.00%																																																																								50.00%												50.00%																			50.00%
Required Customers For Energy Efficiency Programs																																																																				25,000
Required Period For Filing Quick Start Plans																																																																				6 months
Period For Quick Start Plans To Be In Effect																																																																																											2 years	3 years
Percentage Of PSC Retail Rate Increase																																																																												0.90%
Percentage of Decrease in Annual Revenue After Revised Notice																																																																																		0.16%
Decrease in Annual Revenue After Revised Notice																																																																																		1,500,000
Project expenditures, cumulative																																																																									320,600,000
Project expenditures, cumulative, proportionate share																																																																									162,300,000
AFUDC Cost																																																																									8,500,000
Increase (decrease) in annual revenue, percent																																																																																														3.40%
Proposed Change in Annual Revenues																																																																																						10,100,000			1,200,000					30,100,000
Proposed property damage reserve																																																																																3,800,000
PSC Retail Rate Increase																																																																												7,100,000
Period Adjustment For SRR Rate Level																																																																									3 years
PSC Approved Annual Property Damage Reserve Accrual																																																																												3,200,000												3,300,000																												3,500,000
Storm Reserve Balance																																																																									60,100,000
Integrated Coal Gasification Combined Cycle [Abstract]
Plant capacity under coal gasification combined cycle technology in Mega Watts																																																																									582
New Co2 Pipeline Infrastructure																																																																									61
Estimated Cost																																																																																																							2,400,000,000		2,400,000,000	3,250,000,000	[1]
Costs Related to Grant Funding																																																																										245,300,000
Maximum cap construction cost																																																																									2,880,000,000																																	3,990,000,000	[1]
Costs included in CWIP																																							37,000,000																																		2,740,000,000
Loss Contingency, Estimate of Possible Loss																																																																									1,180,000,000																										2,300,000	10,500,000
Cost deferred in other regulatory assets																																																																									70,500,000
Other deferred charges and assets																																																																									3,900,000
Previously expensed																																																																									1,000,000
Pre-Tax Charge To Income							1,200,000,000	1,200,000,000																																																																																																		1,100,000,000		78,000,000
After Tax Charge To Income								729,000,000																																																																																																		680,500,000		48,200,000
Alternate Financing																																																																																																								1,000,000,000
Revenue Requirement Obligations																																																																																																																200,000,000
Settlement Agreement To Increase Rates																																																																																													172,000,000
Increase Retail Rates In Year One																																																																						15.00%
Increase Retail Rates In Year Two																																																																																						3.00%
Settlement Agreement Collection Amount To Mitigate Rate Impact Year Two																																																																													156,000,000
Related regulatory liability																																									62,000,000																																98,100,000
Retail Revenues	14,541,000,000	14,187,000,000	15,071,000,000															4,952,000,000	4,933,000,000	4,972,000,000																			7,620,000,000	7,362,000,000	8,099,000,000																																799,139,000	747,453,000	792,463,000																															10,300,000										1,170,000,000	1,144,471,000	1,208,490,000
Period Rate Plan For Cost Accrued Through Additional Prudence Review																																																																									7 years
Revisions To Revenue Requirement																																																																									35,000,000
Reduced Percentage Interest Transferred under Asset Purchase Agreement																																																																								15.00%
Electric Generating Units, Capacity																		1,000										659																																																																										1,000							75												1,000
Capacity Revenues Under Power Supply Agreement																																																																									17,500,000
Term of management fee contract																																																																									40 years																																								40 years
Percentage of Carbon dioxide captured from project by purchase Denbury																																																																									70.00%
Percentage of contract to purchase carbon dioxide from Kemper IGCC																																																																									30.00%
Purchase of interest in plant																																																																																		17.50%			17.50%
Deposit Received																																																																																	150,000,000						75,000,000
Maximum Period to Refund Deposit upon Termination of Asset Purchase Agreement																																																																									60 days
Maximum Period of Discretion																																																																									15 days
Tax credits (Phase I)																																																																									133,000,000
Tax credits (Phase II)																																																																									279,000,000
Accrued tax benefits on tax credits	28,000,000																																																																								276,400,000
Minimum percentage of carbon dioxide that must be capture and sequester to remain eligible for the phase II tax credits																																																																									65.00%
Prudence Review Of Plant Cost Within Settlement Agreement																																																																									6 months
Annual PEP Filing Rate Increase																																																																															1.925%
Annual PEP Filing Rate Increase Amount																																																																															15,300,000
Estimated Cost of Project One									660,000,000																																																																																												660,000,000															330,000,000
Estimated Cost of Project, Proportionate Share																																																																									330,000,000
Noncash transactions - accrued property additions at year-end																		18,000,000	31,000,000	19,000,000								5,567,000	11,203,000	32,590,000									208,000,000	261,000,000	391,000,000																																164,863,000	214,863,000	135,902,000																																									31,546,000	27,369,000	19,439,000
Base Revenue In Year One																																																																																																																							35,000,000
Base Revenue In Year Two																																																																																																																							20,000,000
Debt Instrument, Interest Rate, Stated Percentage																																																																									9.932%	9.967%	7.13%																																								7.13%															3.7947%
Period of Treasury Rate Above Basis Points																																																																																																																				6 months
Other Cost of Removal Obligations	1,270,000,000	1,194,000,000																828,000,000	759,000,000																				43,000,000	63,000,000																																	151,340,000	143,461,000																																										228,148,000	213,413,000														62,500,000
Recovery Period For Natural Disaster Reserve Costs																		24 months																																																																																																		60 days
Customer Surcharge Storm Recovery Costs																																																																																																																											4
Customer Surcharge Storm Recovery Capacity																																																																																																																											1,000
Cumulative damage costs limit under PSC order																																																																																																																				100,000,000
Retail Rate Increase (Decrease)																																																																																																																								65,200,000
Projected fuel cost over or under recovery threshold, as a percentage of projected fuel revenue																																																																																																																				10.00%						10.00%
Fuel Vendor Payment																																																																																																																														26,600,000
Purchased Power Over (Under) Recovered Balance Percentage																																																																																																																				10.00%
Purchased Power, Over Under Recovered Balance																																																																																																																																2,800,000	800,000
Under Recovered Environmental Cost																																																																																																																																14,400,000	1,900,000
Period of Establishment of Conservation Goals, in Years																																																																																																																				5 years
Period Numeric Conservation Goals Cover, in Years																																																																																																																				10 years
Under Recovered Energy Conservation Costs																																																																																																																																7,000,000
Over Recovered Energy Conservation Costs																																																																																																																																	800,000
Bonus Depreciation for Property Acquired	50.00%																	50.00%										50.00%	50.00%										50.00%																																		50.00%																																											50.00%
Positive Impact From Bonus Depreciation																															$ 98,900,000																																																																															$ 560,000,000	$ 620,000,000

[1] The 2012 MPSC CPCN Order approved a construction cost cap of up to $2.88 billion, net of the DOE Grants and excluding the Cost Cap Exceptions.