ENTERGY STATISTICAL REPORT

AND INVESTOR GUIDE

 2013

Our Vision: We Power Life

Our Mission: Create Sustainable Value for

All Stakeholders - Owners, Customers, Employees and the Communities in Which We Operate

For our owners, we create value by aspiring to provide top-quartile returns

through the relentless pursuit of opportunities to optimize our business

For our customers, we create value by providing safe, secure, reliable service

at reasonable cost

For our employees, we provide a safe, rewarding, diverse and

   inclusive work environment, fair compensation and benefits and opportunities

to advance their careers

For our communities, we create value through economic development,

    philanthropy, volunteerism and advocacy and by operating our business safely

and in a socially and environmentally responsible way

   Entergy Corporation, which celebrated its 100th birthday in 2013, is an

 integrated energy company engaged primarily in electric power production

and retail distribution operations. Entergy owns and operates power plants

with approximately 30,000 megawatts of electric generating capacity,

including more than 10,000 megawatts of nuclear power, making it one of the

nation’s leading nuclear generators. Entergy delivers electricity to 2.8 million

utility customers in Arkansas, Louisiana, Mississippi and Texas. Entergy has

annual revenues of more than $11 billion and approximately 14,000 employees.

We have assembled the statistics and facts in this report to support your

review and analysis of Entergy’s results over the last five years. This

information is available in two electronic files, Excel and PDF in order to

facilitate easier access and analysis.

Entergy Investor Relations

TABLE OF CONTENTS		Note:  The Excel Tab labels correspond to the page numbers
		in the PDF version of the 2013 Statistical Report.
	Excel Tab		Excel Tab
ABOUT THIS PUBLICATION	Page 2	UTILITY SECURITIES DETAIL	Page 31
FORWARD-LOOKING INFORMATION	Page 2	Utility Long-Term Debt and Preferred Stock	Page 31
REGULATION G COMPLIANCE	Page 2	Entergy Arkansas, Inc.	Page 31
ENTERGY AT A GLANCE	Pages 3 – 4	Entergy Gulf States Louisiana, L.L.C.	Page 32
		Entergy Louisiana, LLC	Page 33
ENTERGY CORPORATION AND SUBSIDIARIES		Entergy Mississippi, Inc.	Page 34
Selected Financial and Operating Data	Page 5	Entergy New Orleans, Inc.	Page 34
Selected Financial Data	Page 5	Entergy Texas, Inc.	Page 35
Utility Electric Operating Data	Page 5	System Energy Resources, Inc.	Page 35
Entergy Wholesale Commodities Operating Data	Page 5	UTILITY STATISTICAL INFORMATION	Page 36
Employees	Page 5	Utility Total Capability	Page 36
Owned and Leased Capability	Page 5	Utility Selected Operating Data	Page 36
Consolidated Quarterly Financial Metrics	Page 6	Utility Consolidating Information	Page 37
Consolidated Annual Financial Metrics	Page 6	Entergy Arkansas, Inc.	Pages 38 – 39
Consolidated Financial Results	Page 7	Entergy Gulf States Louisiana, L.L.C.	Pages 40 – 41
Consolidated Quarterly Results	Page 7	Entergy Louisiana, LLC	Pages 42 – 43
Consolidated Quarterly Special Items	Page 8	Entergy Mississippi, Inc.	Pages 44 – 45
Consolidated Annual Results	Page 9	Entergy New Orleans, Inc.	Pages 46 – 47
Consolidated Annual Special Items	Page 10	System Energy Resources, Inc.	Page 47
Description of Consolidated Special Items	Page 11	Entergy Texas, Inc.	Pages 48 – 49
Consolidated Statements of Income	Page 12	Utility Nuclear Plant Statistics	Page 50
Consolidating Income Statement	Page 13	UTILITY REGULATORY INFORMATION	Page 51
Consolidated Balance Sheets	Pages 14 – 15	Regulatory Commissions	Page 51
Consolidating Balance Sheet	Pages 16 – 17	Commission/Council Members	Page 51
Consolidated Statements of Cash Flow	Pages 18 – 19	Utility Electric and Gas Fuel Recovery Mechanisms	Page 52
Cash Flow Information by Business	Page 19
Consolidated Statements of Changes in Equity	Page 20	ENTERGY WHOLESALE COMMODITIES
and Comprehensive Income		EWC Quarterly Financial Metrics	Page 53
Consolidated Statements of Comprehensive	Page 21	EWC Annual Financial Metrics	Page 53
Income		EWC Quarterly Operational Metrics	Page 53
Consolidated Capital Expenditures	Page 22	EWC Annual Operational Metrics	Page 53
Entergy Corporation Securities Detail	Page 22	EWC Total Capacity	Page 53
Entergy Corporation Long-Term Debt	Page 22	EWC Nuclear Plant Statistics	Page 54
Securities Ratings (Outlook)	Page 22	EWC Non-Nuclear Wholesale Assets	Page 54
		Plant Statistics
UTILITY		EWC Non-Nuclear Wholesale Assets	Page 54
Utility Quarterly Financial Metrics	Page 23	Plant Emissions
Utility Annual Financial Metrics	Page 23	EWC Nuclear Securities Detail	Page 55
Utility Securities Ratings (Outlook)	Page 23	EWC Non-Nuclear Wholesale Assets	Page 55
Utility Historical Capital Expenditures	Page 23	Securities Detail
Utility Planned Capital Expenditures	Page 24
Utility Financial Results	Page 25	DEFINITIONS OF OPERATIONAL MEASURES AND
Utility Consolidating Income Statement	Page 25	GAAP AND NON-GAAP FINANCIAL MEASURES	Page 56
Utility Consolidating Balance Sheet	Pages 26 – 27
Utility Selected Annual Financial Metrics	Pages 28 – 30	REG G RECONCILIATIONS
		Financial Measures	Pages 57 – 67
		INVESTOR INFORMATION	Page 68

ABOUT THIS PUBLICATION	● uncertainty regarding the establishment of interim or permanent
This publication is unaudited and should be used in conjunction with Entergy’s	sites for spent nuclear fuel and nuclear waste storage and disposal
2013 Annual Report to Shareholders and Form 10-K filed with the Securities	● variations in weather and the occurrence of hurricanes and other storms
and Exchange Commission. It has been prepared for information purposes and	and disasters, including uncertainties associated with efforts to remediate
is not intended for use in connection with any sale or purchase of, or any offer	the effects of hurricanes, ice storms, or other weather events and the recovery
to buy, any securities of Entergy Corporation or its subsidiaries.	of costs associated with restoration, including accessing funded storm reserves,
	federal and local cost recovery mechanisms, securitization, and insurance
FORWARD-LOOKING INFORMATION	● effects of climate change
In this report and from time to time, Entergy Corporation makes statements concerning	● changes in the quality and availability of water supplies and the related
its expectations, beliefs, plans, objectives, goals, strategies, and future	regulation of water use and diversion
events or performance. Such statements are “forward-looking statements”	● Entergy’s ability to manage its capital projects and operation
within the  meaning of the Private Securities Litigation Reform Act of 1995.	and maintenance costs
Words such as “may,” “will,” “could,” “project,” “believe,” “anticipate,” “intend,”	● Entergy’s ability to purchase and sell assets at attractive prices
“expect,” “estimate,” “continue,” “potential,” “plan,” “predict,” “forecast,”	and on other attractive terms
and other similar words or expressions are intended to identify forward-looking	● the economic climate, and particularly economic conditions in Entergy’s
statements but are not the only means to identify these statements. Although Entergy	Utility service area and the Northeast United States and events
believes that these forward-looking statements and the underlying assumptions are	that could influence economic conditions in those areas
reasonable, it cannot provide assurance that they will prove correct. Any	● the effects of Entergy’s strategies to reduce tax payments
forward-looking statement is based on information current as of the date of this	● changes in the financial markets, particularly those affecting
report and speaks only as of the date on which such statement is made.	the availability of capital and Entergy’s ability to refinance existing debt, execute
Except to the extent required by the federal securities laws, Entergy undertakes	share repurchase programs, and fund investments and acquisitions
no obligation to publicly update or revise any forward-looking statements,	● actions of rating agencies, including changes in the ratings of
whether as a result of new information, future events, or otherwise.	debt and preferred stock, changes in general corporate ratings,
Forward-looking statements involve a number of risks and uncertainties.	and changes in the rating agencies’ ratings criteria
There are factors that could cause actual results to differ materially from those	● changes in inflation and interest rates
expressed or implied in the forward-looking statements, including those	● the effect of litigation and government investigations or proceedings
factors discussed or incorporated by reference in (a) Item 1A. Risk Factors	● changes in technology, including with respect to new, developing, or
in the 2013 Form 10-K, (b) Management’s Financial Discussion and Analysis	alternative sources of generation
in the 2013 Form 10-K, and (c) the following factors (in addition to others	● the potential effects of threatened or actual terrorism, cyber attacks or data
described elsewhere in this report and in subsequent securities filings):	security breaches, including increased security costs, and war or a
● resolution of pending and future rate cases and negotiations,	catastrophic event such as a nuclear accident or a natural gas pipeline
including various performance-based rate discussions,	explosion
Entergy’s utility supply plan, and recovery of fuel and purchased power costs	● Entergy’s ability to attract and retain talented management and directors
● the termination of Entergy Arkansas’s participation in the System Agreement,	● changes in accounting standards and corporate governance
which occurred in December 2013, the termination of Entergy Mississippi's	● declines in the market prices of marketable securities and
participation in the System Agreement in November 2015, the termination of	resulting funding requirements for Entergy’s defined benefit
Entergy Texas's, Entergy Gulf States Louisiana's, and Entergy Louisiana's	pension and other postretirement benefit plans
participation in the System Agreement after expiration of the recently proposed	● future wage and employee benefit costs, including changes
60-month notice period or such other period as approved by the FERC	in discount rates and returns on benefit plan assets
● regulatory and operating challenges and uncertainties and economic risks	● changes in decommissioning trust fund values or earnings
associated with the Utility operating companies’ move to the MISO RTO,	or in the timing of or cost to decommission nuclear plant sites
which occurred in December 2013, including the effect of RTO rules and system	● the implementation of the shutdown of Vermont Yankee by the end of 2014
conditions in the MISO markets, the allocation of MISO system transmission upgrade	and the related decommissioning of Vermont Yankee
costs, and the effect of planning decisions that MISO makes with respect to future	● the effectiveness of Entergy’s risk management policies and
transmission investments by the Utility operating companies	procedures and the ability and willingness of its counterparties
● changes in utility regulation, including the beginning or end of retail and wholesale	to satisfy their financial and performance commitments
competition, the ability to recover net utility assets and other potential stranded	● factors that could lead to impairment of long-lived assets
costs, and the application of more stringent transmission reliability requirements	● the ability to successfully complete merger, acquisition, or
or market power criteria by the FERC	divestiture plans, regulatory or other limitations imposed as a
● changes in regulation of nuclear generating facilities and nuclear materials and fuel,	result of merger, acquisition, or divestiture, and the success of
including with respect to the planned or potential shutdown of nuclear generating facilities	the business following a merger, acquisition, or divestiture
owned or operated by the Entergy Wholesale Commodities business, and the effects of
new or existing safety or environmental concerns regarding nuclear power plants	REGULATION G COMPLIANCE
and nuclear fuel	Financial performance measures shown in this report include those
● resolution of pending or future applications, and related regulatory proceedings	calculated and presented in accordance with generally accepted
and litigation, for license renewals or modifications or other authorizations required	accounting principles (GAAP), as well as those that are considered
of nuclear generating facilities	non-GAAP measures. This report includes non-GAAP measures
● the performance of and deliverability of power from Entergy’s generation	of operational earnings; operational adjusted EBITDA; operational return
resources, including the capacity factors at its nuclear generating facilities	on average invested capital; operational return on average common or
● Entergy’s ability to develop and execute on a point of view regarding future	members’ equity; operational price to earnings ratio; operational common
prices of electricity, natural gas, and other energy-related commodities	dividend payout ratio; gross liquidity, debt to capital ratio, excluding
● prices for power generated by Entergy’s merchant generating	securitization debt; net debt to net capital ratio, excluding securitization debt;
facilities and the ability to hedge, meet credit support requirements for hedges,	net debt to net capital ratio including off-balance sheet liabilities, excluding
sell power forward or otherwise reduce the market price risk associated	securitization debt; total debt, excluding assumption debt; debt to capital
with those facilities, including the Entergy Wholesale Commodities nuclear plants	ratio, excluding assumption debt; and net debt to net capital ratio, excluding
●  the prices and availability of fuel and power Entergy must purchase	assumption debt when describing Entergy’s results of operations and financial
for its Utility customers, and Entergy’s ability to meet credit support	performance. We have prepared reconciliations of these measures to the
requirements for fuel and power supply contracts	most directly comparable GAAP measures. Reconciliations can be found
● volatility and changes in markets for electricity, natural gas,	on pages 7, 9, and 57 – 67.
uranium, and other energy-related commodities
● changes in law resulting from federal or state energy legislation or
legislation subjecting energy derivatives used in hedging and risk
management transactions to governmental regulation
● changes in environmental, tax, and other laws, including requirements for
reduced emissions of sulfur, nitrogen, carbon, greenhouse gases, mercury,
and other regulated air and water emissions, and changes in costs of
compliance with environmental and other laws and regulations

ENTERGY AT A GLANCE

BUSINESS SEGMENT STRUCTURE

Above diagram represents business segment structure and does not necessarily represent legal entity organization structure.
CORPORATE PROFILE	BUSINESS SEGMENTS
Entergy Corporation is a Fortune 500 integrated energy company	Entergy’s five year results in this report are presented in
engaged primarily in electric power production and retail	three business segments:
distribution operations.
●  Approximately 30,000 MW electric generating capacity	●  Utility
●  More than 10,000 MW nuclear power	●  Entergy Wholesale Commodities
●  2.8 million utility customers	●  Parent and Other
●  More than $11 billion annual revenues
●  Approximately 14,000 employees	In fourth quarter 2012, Entergy included subsidiaries
●  84 electric generating units operated	previously included and reported in the
	Parent & Other segment in the Entergy Wholesale
	Commodities segment to improve the alignment of certain
	intercompany items. The prior period financial information
	in this report has been restated to reflect this change.

ENTERGY CORPORATION AND SUBSIDIARIES
BUSINESS SEGMENTS (CONTINUED)
UTILITY	ENTERGY WHOLESALE COMMODITIES
Entergy’s utility companies generate, transmit, distribute, and sell	Entergy’s Wholesale Commodities business owns and operates six nuclear
electric power, and operate a small natural gas distribution business.	units in the northern United States. This business is focused on selling power
●  Six electric utilities with 2.8 million customers	produced by those plants to wholesale customers. Entergy’s Wholesale
●  Four states – Arkansas, Louisiana, Mississippi, Texas	Commodities business also owns interests in non-nuclear power plants that
●  22,000 MW generating capacity	sell the electric power produced by those plants to wholesale customers.
●  Two gas utilities with 196,000 customers	This business also provides services to other nuclear power plant owners.
	●  5,011 MW nuclear-owned generating capacity in six units in northern U.S.
ENTERGY ARKANSAS, INC. (EAI)	●  Pilgrim Nuclear Station in Plymouth, Massachusetts
Entergy Arkansas generates, transmits, distributes, and sells electric	●  James A. FitzPatrick in Oswego, New York
power to 700,000 retail customers in portions of Arkansas.	●  Indian Point Units 2 and 3 in Buchanan, New York
	●  Vermont Yankee in Vernon, Vermont
ENTERGY GULF STATES LOUISIANA, L.L.C. (EGSL)	●  Palisades Nuclear Energy Plant in Covert, Michigan
Entergy Gulf States Louisiana generates, transmits, distributes, and	●  1,057 net MW non-nuclear generating capacity
sells electric power to 392,000 retail customers in portions of	●  800 MW under management services contract
Louisiana. Entergy Gulf States Louisiana also provides natural gas	●  Cooper Nuclear Station located near Brownville, Nebraska
utility service to 93,000 customers in the Baton Rouge, Louisiana area.	●  Contracts (ongoing and completed) with other nuclear facility owners to
	provide decommissioning and license renewal services
ENTERGY LOUISIANA, LLC (ELL)
Entergy Louisiana generates, transmits, distributes, and sells electric	In August 2013, Entergy announced plans to close and decommission
power to 677,000 retail customers in portions of Louisiana.	Vermont Yankee. The plant is expected to cease power production in
	fourth quarter 2014 when its current fuel cycle ends.
ENTERGY MISSISSIPPI, INC. (EMI)
Entergy Mississippi generates, transmits, distributes, and sells electric	In November 2013, Entergy sold Entergy Solutions District Energy,
power to 441,000 retail customers in portions of Mississippi.	a business wholly-owned by Entergy in the Entergy Wholesale Commodities
	segment that owns and operates district energy assets serving the business
ENTERGY NEW ORLEANS, INC. (ENOI)	districts in Houston and New Orleans. Entergy sold Entergy Solutions District
Entergy New Orleans generates, transmits, distributes, and sells	Energy for $140 million and realized a pre-tax gain of $44 million on the sale.
electric power to 168,000 retail customers in the city of New Orleans,
Louisiana. Entergy New Orleans also provides natural gas utility
service to 103,000 customers in the city of New Orleans.
ENTERGY TEXAS, INC. (ETI)
Entergy Texas generates, transmits, distributes, and sells electric power
to 422,000 retail customers in portions of Texas.
SYSTEM ENERGY RESOURCES, INC. (SERI)
System Energy owns or leases 90% of the Grand Gulf 1 nuclear
generating facility. System Energy sells energy and capacity from
Grand Gulf 1 at wholesale to Entergy Arkansas (36%), Entergy Louisiana (14%),
Entergy Mississippi (33%) and Entergy New Orleans (17%).
UTILITY NUCLEAR PLANTS
Entergy owns and operates five nuclear units at four plant sites to serve
its regulated utility business: Arkansas Nuclear One (ANO) Units 1 and 2
near Russellville, Arkansas; Grand Gulf Nuclear Station in Port Gibson,
Mississippi; River Bend Station in St. Francisville, Louisiana and
Waterford 3 in Killona, Louisiana.

SELECTED FINANCIAL AND OPERATING DATA
SELECTED FINANCIAL DATA
(In millions, except percentages, per share amounts, and ratios)	2013			2012			2011			2010			2009
GAAP MEASURES
Operating Revenues	$	11,391		$	10,302		$	11,229		$	11,488		$	10,746
As-Reported Net Income	$	712		$	847		$	1,346		$	1,250		$	1,231
As-Reported Earnings Per Share	$	3.99		$	4.76		$	7.55		$	6.66		$	6.30
Shares of Common Stock Outstanding:
End of Year		178.4			177.8			176.4			178.7			189.1
Weighted Average – Diluted		178.6			177.7			178.4			187.8			195.8
Return on Average Invested Capital – As-Reported		4.7	%		5.5	%		8.0	%		7.8	%		7.7	%
Return on Average Common Equity – As-Reported		7.6	%		9.3	%		15.4	%		14.6	%		14.9	%
Net Cash Flow Provided by Operating Activities	$	3,189		$	2,940		$	3,129		$	3,926		$	2,933
Year-End Closing Market Price Per Share of Common Stock	$	63.27		$	63.75		$	73.05		$	70.83		$	81.84
Book Value Per Share at End of Year	$	54.00		$	51.72		$	50.81		$	47.53		$	45.54
Market Value of Equity at End of Year	$	11,286		$	11,335		$	12,883		$	12,661		$	15,477
Price to Earnings Ratio – As-Reported		15.87			13.39			9.68			10.64			12.99
Common Dividend Paid Per Share	$	3.32		$	3.32		$	3.32		$	3.24		$	3.00
Common Dividend Payout Ratio – As-Reported		83	%		70	%		44	%		49	%		48	%
NON-GAAP MEASURES
Operational Earnings	$	957		$	1,109		$	1,359		$	1,332		$	1,302
Operational Earnings Per Share	$	5.36		$	6.23		$	7.62		$	7.10		$	6.67
Special Items Per Share	$	(1.37	)	$	(1.47	)	$	(0.07	)	$	(0.44	)	$	(0.37	)
Return on Average Invested Capital – Operational		5.8	%		6.6	%		8.0	%		8.2	%		8.1	%
Return on Average Common Equity – Operational		10.2	%		12.2	%		15.6	%		15.6	%		15.7	%
Price to Earnings Ratio – Operational		11.80			10.23			9.59			9.98			12.27
Common Dividend Payout Ratio – Operational		62	%		53	%		44	%		46	%		45	%
UTILITY ELECTRIC OPERATING DATA
		2013			2012			2011			2010			2009
Retail Kilowatt-Hour Sales (millions)		107,781			107,004			108,688			107,510			99,148
Peak Demand (megawatts)		21,581			21,866			22,387			21,799			21,009
Retail Customers – Year End (thousands)		2,800			2,778			2,757			2,743			2,719
ENTERGY WHOLESALE COMMODITIES OPERATING DATA
		2013			2012			2011			2010			2009
Operating Revenues (millions)(a)	$	2,313		$	2,326		$	2,414		$	2,566		$	2,711
Billed Electric Energy Sales  (gigawatt hours)		45,127			46,178			43,497			42,934			43,743
(a) Includes revenue associated with below-market PPA for Palisades of $17,654,839 for 2013, $16,724,963 for 2012, $42,996,197 for 2011, $46,296,187 for 2010, and $52,520,249 for 2009.
EMPLOYEES
		2013			2012			2011			2010			2009
Total Employees – Year End		13,808			14,625			14,682			14,958			15,181

OWNED AND LEASED CAPABILITY (MW)(a)
As of December 31, 2013
			Entergy												Entergy
	Entergy		Gulf States		Entergy		Entergy		Entergy		Entergy		System		Wholesale
	Arkansas		Louisiana		Louisiana		Mississippi		New Orleans		Texas		Energy		Commodities(c)(d)		Total
Gas/Oil		1,646		1,634		4,903		3,000		781		2,283		-		796		15,043
Coal		1,197		367		-		420		-		271		-		181		2,436
Total Fossil		2,843		2,001		4,903		3,420		781		2,554		-		977		17,479
Nuclear		1,819		968		1,156		-		-		-		1,272		5,011		10,226
Other(b)		74		-		-		-		-		-		-		80		154
Total		4,736		2,969		6,059		3,420		781		2,554		1,272		6,068		27,859
(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments)
that each station was designed to utilize.
(b) Other includes Hydro (EAI) and Wind (EWC).
(c) Reflects Net MW in Operation. Net MW in Operation is the installed capacity owned and operated. Excludes management services contract for Cooper Nuclear Station.
(d) Reflects nameplate rating of generating unit and excludes capacity under contract.

CONSOLIDATED ENTERGY CORPORATION AND SUBSIDIARIES DATA
CONSOLIDATED QUARTERLY FINANCIAL METRICS
	2013											2012											YTD %
		1	Q	2	Q	3	Q	4	Q	YTD			1	Q	2	Q	3	Q	4	Q	YTD		CHANGE
GAAP MEASURES
As-Reported Net Income ($ millions)		161.4		163.7		239.9		146.9			711.9		(151.7	)	365.0		337.1		296.3			846.7		(15.9	)
Return on Average Invested Capital –
As-Reported (%)(a)		6.9		5.9		5.5		4.7			4.7		6.0		6.2		4.8		5.5			5.5		(14.5	)
Return on Average Common Equity –
As-Reported (%)(a)		12.8		10.5		9.3		7.6			7.6		10.8		11.3		7.8		9.3			9.3		(18.3	)
Cash Flow Interest Coverage (# times)(a)		5.9		5.8		5.9		6.2			6.2		7.5		7.2		6.8		6.1			6.1		1.6
Revolver Capacity ($ millions)		3,542		3,819		4,129		3,977			3,977		2,825		2,762		2,917		3,462			3,462		14.9
Total Debt ($ millions)		13,471		13,747		13,623		13,678			13,678		12,619		12,533		12,931		13,473			13,473		1.5
Debt to Capital Ratio (%)		58.7		59.0		58.4		57.9			57.9		57.9		57.4		57.7		58.7			58.7		(1.4	)
Off-Balance Sheet Liabilities ($ millions)		595		594		592		542			542		601		600		599		595			595		(8.9	)
NON-GAAP MEASURES
Operational Earnings ($ millions)		167.7		179.7		430.4		179.3			957.1		79.0		374.6		347.8		307.1			1,108.5		(13.7	)
Return on Average Invested Capital –
Operational (%)(a)		7.0		6.1		6.4		5.8			5.8		7.2		7.4		6.0		6.6			6.6		(12.1	)
Return on Average Common Equity –
Operational (%)(a)		13.2		10.9		11.7		10.2			10.2		13.6		14.2		10.7		12.2			12.2		(16.4	)
Total Gross Liquidity ($ millions)		3,805		4,130		4,494		4,716			4,716		3,510		3,045		3,667		3,995			3,995		18.0
Debt to Capital Ratio,      Excluding Securitization Debt (%)		56.9		57.3		56.7		56.3			56.3		55.7		55.3		55.7		56.9			56.9		(1.1	)
Net Debt to Net Capital Ratio,      Excluding Securitization Debt (%)		56.3		56.7		56.0		54.8			54.8		54.2		54.7		54.1		55.8			55.8		(1.8	)
Net Debt to Net Capital Ratio Including
Off-Balance Sheet Liabilities,       Excluding Securitization Debt (%)		57.5		57.8		57.2		55.9			55.9		55.5		56.0		55.4		57.0			57.0		(1.9	)
(a) Rolling twelve months. Totals may not foot due to rounding.

CONSOLIDATED ANNUAL FINANCIAL METRICS
	2013		2012		2011		2010		2009
GAAP MEASURES
As-Reported Net Income ($ millions)		712		847		1,346		1,250		1,231
Return on Average Invested Capital – As-Reported (%)		4.7		5.5		8.0		7.8		7.7
Return on Average Common Equity – As-Reported (%)		7.6		9.3		15.4		14.6		14.9
Cash Flow Interest Coverage (# times)		6.2		6.1		7.1		7.8		6.1
Revolver Capacity ($ millions)		3,977		3,462		2,001		2,354		1,464
Total Debt ($ millions)		13,678		13,473		12,387		11,816		12,014
Debt to Capital Ratio (%)		57.9		58.7		57.3		57.3		57.4
Off-Balance Sheet Liabilities ($ millions)
Debt of Joint Ventures – Entergy’s Share		86		90		94		107		116
Leases – Entergy’s Share		456		505		508		546		530
Total		542		595		602		653		646
NON-GAAP MEASURES
Operational Earnings ($ millions)		957		1,109		1,359		1,332		1,302
Return on Average Invested Capital – Operational (%)		5.8		6.6		8.0		8.2		8.1
Return on Average Common Equity – Operational (%)		10.2		12.2		15.6		15.6		15.7
Total Gross Liquidity ($ millions)		4,716		3,995		2,695		3,648		3,174
Debt to Capital Ratio,      Excluding Securitization Debt (%)		56.3		56.9		55.0		55.3		55.6
Net Debt to Net Capital Ratio, Excluding Securitization Debt (%)		54.8		55.8		53.5		52.1		51.5
Net Debt to Net Capital Ratio Including Off-Balance Sheet
Liabilities, Excluding Securitization Debt (%)		55.9		57.0		54.8		53.8		53.1
Totals may not foot due to rounding.

FINANCIAL RESULTS
ENTERGY CORPORATION CONSOLIDATED QUARTERLY RESULTS – GAAP TO NON-GAAP RECONCILIATION
	2013												2012												YTD
($/share)		1	Q	2	Q	3	Q	4	Q	YTD				1	Q	2	Q	3	Q	4	Q	YTD			CHANGE
AS-REPORTED
Utility		0.69		1.10		1.95		0.90			4.64			0.35		1.72		1.66		1.57			5.30			(0.66	)
Entergy Wholesale Commodities		0.46		0.06		(0.52	)	0.24			0.24			(0.99	)	0.40		0.49		0.33			0.23			0.01
Parent & Other		(0.25	)	(0.24	)	(0.09	)	(0.32	)		(0.89	)		(0.22	)	(0.06	)	(0.26	)	(0.24	)		(0.77	)		(0.12	)
CONSOLIDATED AS-REPORTED EARNINGS		0.90		0.92		1.34		0.82			3.99			(0.86	)	2.06		1.89		1.66			4.76			(0.77	)
LESS SPECIAL ITEMS
Utility		(0.04	)	(0.08	)	(0.09	)	0.04			(0.16	)		(0.03	)	(0.05	)	(0.06	)	(0.06	)		(0.21	)		0.05
Entergy Wholesale Commodities		-		(0.01	)	(0.98	)	(0.24	)		(1.23	)		(1.26	)	-		-		-			(1.26	)		0.03
Parent & Other		-		-		-		0.02			0.02			(0.01	)	-		-		-			-			0.02
TOTAL SPECIAL ITEMS		(0.04	)	(0.09	)	(1.07	)	(0.18	)		(1.37	)		(1.30	)	(0.05	)	(0.06	)	(0.06	)		(1.47	)		0.10
OPERATIONAL
Utility		0.73		1.18		2.04		0.86			4.80			0.38		1.77		1.72		1.63			5.51			(0.71	)
Entergy Wholesale Commodities		0.46		0.07		0.46		0.48			1.47			0.27		0.40		0.49		0.33			1.49			(0.02	)
Parent & Other		(0.25	)	(0.24	)	(0.09	)	(0.34	)		(0.91	)		(0.21	)	(0.06	)	(0.26	)	(0.24	)		(0.77	)		(0.14	)
CONSOLIDATED OPERATIONAL EARNINGS		0.94		1.01		2.41		1.00			5.36			0.44		2.11		1.95		1.72			6.23			(0.87	)
Weather Impact		(0.10	)	(0.02	)	0.01		0.11			-			(0.18	)	0.08		0.08		(0.07	)		(0.09	)		0.09
SHARES OF COMMON STOCK
OUTSTANDING (in millions)
End of Period		178.1		178.2		178.3		178.4			178.4			177.2		177.2		177.7		177.8			177.8			0.6
Weighted Average - Diluted		178.4		178.6		178.7		178.8			178.6			177.4		177.6		178.0		178.0			177.7			0.9
Totals may not foot due to rounding.

FINANCIAL RESULTS
ENTERGY CORPORATION CONSOLIDATED QUARTERLY SPECIAL ITEMS (Shown as Positive/(Negative) Impact on Earnings)
	2013												2012												YTD
($/share)		1	Q	2	Q	3	Q	4	Q	YTD				1	Q	2	Q	3	Q	4	Q	YTD			CHANGE
UTILITY
SPECIAL ITEMS
Transmission business spin-merge expenses		(0.04	)	(0.07	)	(0.06	)	0.11			(0.05	)		(0.03	)	(0.05	)	(0.06	)	(0.06	)		(0.21	)		0.16
HCM implementation expenses		-		(0.01	)	(0.03	)	(0.07	)		(0.11	)		-		-		-		-			-			(0.11	)
Total		(0.04	)	(0.08	)	(0.09	)	0.04			(0.16	)		(0.03	)	(0.05	)	(0.06	)	(0.06	)		(0.21	)		0.05
ENTERGY WHOLESALE COMMODITIES
SPECIAL ITEMS
VY asset impairments/related charges		-		-		(0.97	)	(0.18	)		(1.15	)		(1.26	)	-		-		-			(1.26	)		0.11
HCM implementation expenses		-		(0.01	)	(0.01	)	(0.06	)		(0.08	)		-		-		-		-			-			(0.08	)
Total		-		(0.01	)	(0.98	)	(0.24	)		(1.23	)		(1.26	)	-		-		-			(1.26	)		0.03
PARENT & OTHER
SPECIAL ITEMS
Transmission business spin-merge expenses		-		-		-		0.03			0.03			(0.01	)	-		-		-			-			0.03
HCM implementation expenses		-		-		-		(0.01	)		(0.01	)		-		-		-		-			-			(0.01	)
Total		-		-		-		0.02			0.02			(0.01	)	-		-		-			-			0.02
TOTAL SPECIAL ITEMS		(0.04	)	(0.09	)	(1.07	)	(0.18	)		(1.37	)		(1.30	)	(0.05	)	(0.06	)	(0.06	)		(1.47	)		0.10
	2013												2012												YTD
($ millions)		1	Q	2	Q	3	Q	4	Q	YTD				1	Q	2	Q	3	Q	4	Q	YTD			CHANGE
UTILITY
SPECIAL ITEMS
Transmission business spin-merge expenses		(6.3	)	(12.2	)	(10.1	)	20.0			(8.7	)		(5.8	)	(9.9	)	(10.7	)	(10.7	)		(37.1	)		28.4
HCM implementation expenses		-		(2.7	)	(5.2	)	(12.5	)		(20.3	)		-		-		-		-			-			(20.3	)
Total		(6.3	)	(14.9	)	(15.3	)	7.5			(29.0	)		(5.8	)	(9.9	)	(10.7	)	(10.7	)		(37.1	)		8.1
ENTERGY WHOLESALE COMMODITIES
SPECIAL ITEMS
VY asset impairments/related charges		-		-		(173.1	)	(31.8	)		(204.8	)		(223.5	)	-		-		-			(223.5	)		18.7
HCM implementation expenses		-		(1.1	)	(2.1	)	(11.8	)		(15.0	)		-		-		-		-			-			(15.0	)
Total		-		(1.1	)	(175.2	)	(43.6	)		(219.8	)		(223.5	)	-		-		-			(223.5	)		3.7
PARENT & OTHER
SPECIAL ITEMS
Transmission business spin-merge expenses		-		-		-		5.5			5.5			(1.4	)	0.3		-		-			(1.0	)		6.5
HCM implementation expenses		-		-		-		(1.8	)		(1.9	)		-		-		-		-			-			(1.9	)
Total		-		-		-		3.7			3.6			(1.4	)	0.3		-		-			(1.0	)		4.6
TOTAL SPECIAL ITEMS		(6.3	)	(16.0	)	(190.5	)	(32.4	)		(245.2	)		(230.7	)	(9.6	)	(10.7	)	(10.7	)		(261.6	)		16.4
Totals may not foot due to rounding.

FINANCIAL RESULTS
ENTERGY CORPORATION CONSOLIDATED ANNUAL RESULTS – GAAP TO NON-GAAP RECONCILIATION
($/share)	2013			2012			2011			2010			2009
AS-REPORTED
Utility		4.64			5.30			6.20			4.33			3.53
Entergy Wholesale Commodities		0.24			0.23			2.74			2.38			3.10
Parent & Other		(0.89	)		(0.77	)		(1.39	)		(0.05	)		(0.33	)
CONSOLIDATED AS-REPORTED EARNINGS		3.99			4.76			7.55			6.66			6.30
LESS SPECIAL ITEMS
Utility		(0.16	)		(0.21	)		-			-			-
Entergy Wholesale Commodities		(1.23	)		(1.26	)		-			(0.54	)		(0.23	)
Parent & Other		0.02			-			(0.07	)		0.10			(0.14	)
TOTAL SPECIAL ITEMS		(1.37	)		(1.47	)		(0.07	)		(0.44	)		(0.37	)
OPERATIONAL
Utility		4.80			5.51			6.20			4.33			3.53
Entergy Wholesale Commodities		1.47			1.49			2.74			2.92			3.33
Parent & Other		(0.91	)		(0.77	)		(1.32	)		(0.15	)		(0.19	)
CONSOLIDATED OPERATIONAL EARNINGS		5.36			6.23			7.62			7.10			6.67
Weather Impact		-			(0.09	)		0.52			0.62			(0.01	)

FINANCIAL RESULTS
ENTERGY CORPORATION CONSOLIDATED ANNUAL SPECIAL ITEMS (Shown as Positive/(Negative) Impact on Earnings)
($/share)	2013			2012			2011			2010			2009
UTILITY SPECIAL ITEMS
Transmission business spin-merge expenses		(0.05	)		(0.21	)		-			-			-
HCM implementation expenses		(0.11	)		-			-			-			-
Total		(0.16	)		(0.21	)		-			-			-
ENTERGY WHOLESALE COMMODITIES SPECIAL ITEMS
VY asset impairments/related charges		(1.15	)		(1.26	)		-			-			-
HCM implementation expenses		(0.08	)		-			-			-			-
Non-utility nuclear spin-off expenses		-			-			-			(0.54	)		(0.23	)
Total		(1.23	)		(1.26	)		-			(0.54	)		(0.23	)
PARENT & OTHER SPECIAL ITEMS
Transmission business spin-merge expenses		0.03			-			(0.07	)		-			-
HCM implementation expenses		(0.01	)		-			-			-			-
Non-utility nuclear spin-off expenses		-			-			-			0.10			(0.14	)
Total		0.02			-			(0.07	)		0.10			(0.14	)
TOTAL SPECIAL ITEMS		(1.37	)		(1.47	)		(0.07	)		(0.44	)		(0.37	)
($ millions)		2013			2012			2011			2010			2009
UTILITY SPECIAL ITEMS
Transmission business spin-merge expenses		(8.7	)		(37.1	)		-			-			-
HCM implementation expenses		(20.3	)		-			-			-			-
Total		(29.0	)		(37.1	)		-			-			-
ENTERGY WHOLESALE COMMODITIES SPECIAL ITEMS
VY asset impairments/related charges		(204.8	)		(223.5	)		-			-			-
HCM implementation expenses		(15.0	)		-			-			-			-
Non-utility nuclear spin-off expenses		-			-			-			(100.7	)		(44.0	)
Total		(219.8	)		(223.5	)		-			(100.7	)		(44.0	)
PARENT & OTHER SPECIAL ITEMS
Transmission business spin-merge expenses		5.5			(1.0	)		(13.0	)		-			-
HCM implementation expenses		(1.9	)		-			-			-			-
Non-utility nuclear spin-off expenses		-			-			-			18.5			(27.0	)
Total		3.6			(1.0	)		(13.0	)		18.5			(27.0	)
TOTAL SPECIAL ITEMS		(245.2	)		(261.6	)		(13.0	)		(82.2	)		(71.0	)

FINANCIAL RESULTS
DESCRIPTION OF ENTERGY CORPORATION CONSOLIDATED SPECIAL ITEMS
	MAIN EARNINGS CATEGORY
UTILITY SPECIAL ITEMS
Transmission business spin-merge expenses	Operating expenses: Other operation and maintenance  Income taxes
HCM implementation expenses	Operating expenses: Other operation and maintenance
ENTERGY WHOLESALE COMMODITIES SPECIAL ITEMS
VY asset impairments/related charges	Operating expenses: Other operation and maintenance   Income taxes
HCM implementation expenses	Operating expenses: Other operation and maintenance
Non-utility nuclear spin-off expenses	Operating expenses: Other operation and maintenance  Operating expenses: Taxes other than income taxes  Operating expenses: Depreciation  Interest and Other Charges: Other interest
PARENT & OTHER SPECIAL ITEMS
Transmission business spin-merge expenses	Operating expenses: Other operation and maintenance  Income taxes
HCM implementation expenses	Operating expenses: Other operation and maintenance
Non-utility nuclear spin-off expenses	Operating expenses: Other operation and maintenance  Income taxes

FINANCIAL RESULTS
CONSOLIDATED STATEMENTS OF INCOME (unaudited)
In thousands, except share data, for the years ended December 31,	2013			2012			2011			2010			2009
OPERATING REVENUES:
Electric	$	8,942,360		$	7,870,649		$	8,673,517		$	8,740,637		$	7,880,016
Natural gas		154,353			130,836			165,819			197,658			172,213
Competitive businesses		2,294,234			2,300,594			2,389,737			2,549,282			2,693,421
Total		11,390,947			10,302,079			11,229,073			11,487,577			10,745,650
OPERATING EXPENSES:
Operating and maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		2,445,818			2,036,835			2,492,714			2,518,582			2,309,831
Purchased power		1,554,332			1,255,800			1,564,967			1,659,416			1,395,203
Nuclear refueling outage expenses		256,801			245,600			255,618			256,123			241,310
Asset impairments and related charges		341,537			355,524			-			-			-
Other operation and maintenance		3,331,934			3,045,392			2,867,758			2,969,402			2,750,810
Decommissioning		242,104			184,760			190,595			211,736			199,063
Taxes other than income taxes		600,350			557,298			536,026			534,299			503,859
Depreciation and amortization		1,261,044			1,144,585			1,102,202			1,069,894			1,082,775
Other regulatory charges (credits) – net		45,597			175,104			205,959			44,921			(21,727	)
Total		10,079,517			9,000,898			9,215,839			9,264,373			8,461,124
Gain on sale of business		43,569			-			-			44,173			-
OPERATING INCOME		1,354,999			1,301,181			2,013,234			2,267,377			2,284,526
OTHER INCOME (DEDUCTIONS):
Allowance for equity funds used during construction		66,053			92,759			84,305			59,381			59,545
Interest and investment income		199,300			127,776			128,994			184,077			236,628
Other than temporary impairment losses		-			-			-			-			(86,069	)
Miscellaneous – net		(59,762	)		(53,214	)		(59,271	)		(48,124	)		(40,396	)
Total		205,591			167,321			154,028			195,334			169,708
INTEREST EXPENSE:
Interest expense		629,537			606,596			551,521			610,146			603,679
Allowance for borrowed funds used during construction		(25,500	)		(37,312	)		(37,894	)		(34,979	)		(33,235	)
Total		604,037			569,284			513,627			575,167			570,444
INCOME BEFORE INCOME TAXES		956,553			899,218			1,653,635			1,887,544			1,883,790
Income taxes		225,981			30,855			286,263			617,239			632,740
CONSOLIDATED NET INCOME		730,572			868,363			1,367,372			1,270,305			1,251,050
Preferred dividend requirements of subsidiaries		18,670			21,690			20,933			20,063			19,958
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION	$	711,902		$	846,673		$	1,346,439		$	1,250,242		$	1,231,092
Basic earnings per average common share	$	3.99		$	4.77		$	7.59		$	6.72		$	6.39
Diluted earnings per average common share	$	3.99		$	4.76		$	7.55		$	6.66		$	6.30
Average number of common shares outstanding:
Basic		178,211,192			177,324,813			177,430,208			186,010,452			192,772,032
Diluted		178,570,400			177,737,565			178,370,695			187,814,235			195,838,068
Certain prior year data has been reclassified to conform with current year presentation.

FINANCIAL RESULTS
2013 CONSOLIDATING INCOME STATEMENT (unaudited)
				ENTERGY
				WHOLESALE			PARENT &
In thousands, except share data, for the year ended December 31, 2013.	UTILITY			COMMODITIES			OTHER			CONSOLIDATED
OPERATING REVENUES:
Electric	$	8,947,433		$	-		$	(5,073	)	$	8,942,360
Natural gas		154,353			-			-			154,353
Competitive businesses		-			2,312,758			(18,524	)		2,294,234
Total		9,101,786			2,312,758			(23,597	)		11,390,947
OPERATING EXPENSES:
Operating and maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		2,036,749			411,233			(2,164	)		2,445,818
Purchased power		1,495,643			99,460			(40,771	)		1,554,332
Nuclear refueling outage expenses		124,960			131,841			-			256,801
Asset impairments and related charges		9,411			329,336			2,790			341,537
Other operation and maintenance		2,263,894			1,048,061			19,979			3,331,934
Decommissioning		116,812			125,292			-			242,104
Taxes other than income taxes		469,969			129,020			1,361			600,350
Depreciation and amortization		1,041,031			215,871			4,142			1,261,044
Other regulatory charges (credits) - net		45,597			-			-			45,597
Total		7,604,066			2,490,114			(14,663	)		10,079,517
Gain on sale of business		-			43,569			-			43,569
OPERATING INCOME		1,497,720			(133,787	)		(8,934	)		1,354,999
OTHER INCOME (DEDUCTIONS):
Allowance for equity funds used during construction		66,053			-			-			66,053
Interest and investment income		186,724			137,727			(125,151	)		199,300
Miscellaneous – net		(29,192	)		(22,112	)		(8,458	)		(59,762	)
Total		223,585			115,615			(133,609	)		205,591
INTEREST EXPENSE:
Interest expense		534,673			16,323			78,541			629,537
Allowance for borrowed funds used during construction		(25,500	)		-			-			(25,500	)
Total		509,173			16,323			78,541			604,037
INCOME BEFORE INCOME TAXES		1,212,132			(34,495	)		(221,084	)		956,553
Income taxes		365,917			(77,471	)		(62,465	)		225,981
CONSOLIDATED NET INCOME		846,215			42,976			(158,619	)		730,572
Preferred dividend requirements of subsidiaries		17,329			91			1,250			18,670
NET INCOME ATTRIBUTABLE TO ENTERGY CORPORATION	$	828,886		$	42,885		$	(159,869	)	$	711,902
Basic earnings per average common share	$	4.65		$	0.24		$	(0.90	)	$	3.99
Diluted earnings per average common share	$	4.64		$	0.24		$	(0.89	)	$	3.99
Totals may not foot due to rounding.

FINANCIAL RESULTS
CONSOLIDATED BALANCE SHEETS (unaudited)
In thousands, as of December 31,	2013			2012			2011			2010			2009
ASSETS
CURRENT ASSETS:
Cash and cash equivalents:
Cash	$	129,979		$	112,992		$	81,468		$	76,290		$	85,861
Temporary cash investments		609,147			419,577			612,970			1,218,182			1,623,690
Total cash and cash equivalents		739,126			532,569			694,438			1,294,472			1,709,551
Securitization recovery trust account		45,885			46,040			50,304			43,044			13,098
Accounts receivable:
Customer		670,641			568,871			568,558			602,796			553,692
Allowance for doubtful accounts		(34,311	)		(31,956	)		(31,159	)		(31,777	)		(27,631	)
Other		195,028			161,408			166,186			161,662			152,303
Accrued unbilled revenues		340,828			303,392			298,283			302,901			302,463
Total accounts receivable		1,172,186			1,001,715			1,001,868			1,035,582			980,827
Deferred fuel costs		116,379			150,363			209,776			64,659			126,798
Accumulated deferred income taxes		175,073			306,902			9,856			8,472			-
Fuel inventory – at average cost		208,958			213,831			202,132			207,520			196,855
Materials and supplies – at average cost		915,006			928,530			894,756			866,908			825,702
Deferred nuclear refueling outage costs		192,474			243,374			231,031			218,423			225,290
System agreement cost equalization		61,040			16,880			36,800			52,160			70,000
Prepaid taxes		-			-			-			301,807			184,819
Prepayments and other		303,564			242,922			291,742			246,036			201,221
Total		3,929,691			3,683,126			3,622,703			4,339,083			4,534,161
OTHER PROPERTY AND INVESTMENTS:
Investment in affiliates – at equity		40,350			46,738			44,876			40,697			39,580
Decommissioning trust funds		4,903,144			4,190,108			3,788,031			3,595,716			3,211,183
Non-utility property – at cost (less accumulated depreciation)		199,375			256,039			260,436			257,847			247,664
Other		210,616			436,234			416,423			405,946			120,273
Total		5,353,485			4,929,119			4,509,766			4,300,206			3,618,700
PROPERTY, PLANT AND EQUIPMENT:
Electric		42,935,712			41,944,567			39,385,524			37,153,061			36,343,772
Property under capital lease		941,299			935,199			809,449			800,078			783,096
Natural gas		366,365			353,492			343,550			330,608			314,256
Construction work in progress		1,514,857			1,365,699			1,779,723			1,661,560			1,547,319
Nuclear fuel under capital lease		-			-			-			-			527,521
Nuclear fuel		1,566,904			1,598,430			1,546,167			1,377,962			739,827
Total property, plant and equipment		47,325,137			46,197,387			43,864,413			41,323,269			40,255,791
Less – accumulated depreciation and amortization		19,443,493			18,898,842			18,255,128			17,474,914			16,866,389
Property, plant and equipment – net		27,881,644			27,298,545			25,609,285			23,848,355			23,389,402
DEFERRED DEBITS AND OTHER ASSETS:
Regulatory assets:
Regulatory asset for income taxes - net		849,718			742,030			799,006			845,725			816,856
Other regulatory assets (includes securitization property of
$822,218 as of December 31, 2013, $914,751 as
of December 31, 2012, $1,009,103 as of December 31, 2011,
$882,346 as of December 31, 2010,
$818,047 as of December 31, 2009)		3,893,363			5,025,912			4,636,871			3,838,237			3,647,154
Deferred fuel costs		172,202			172,202			172,202			172,202			172,202
Goodwill		377,172			377,172			377,172			377,172			377,172
Accumulated deferred income taxes		62,011			37,748			19,003			54,523			-
Other		887,160			936,648			955,691			909,773			1,006,306
Total		6,241,626			7,291,712			6,959,945			6,197,632			6,019,690
TOTAL ASSETS	$	43,406,446		$	43,202,502		$	40,701,699		$	38,685,276		$	37,561,953
Certain prior year data has been reclassified to conform with current year presentation.

FINANCIAL RESULTS
CONSOLIDATED BALANCE SHEETS (unaudited)
In thousands, as of December 31,	2013			2012			2011			2010			2009
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Currently maturing long-term debt	$	457,095		$	718,516		$	2,192,733		$	299,548		$	711,957
Notes payable and commercial paper		1,046,887			796,002			108,331			154,135			30,031
Accounts payable		1,173,313			1,217,180			1,069,096			1,181,099			998,228
Customer deposits		370,997			359,078			351,741			335,058			323,342
Taxes accrued		191,093			333,719			278,235			-			-
Accumulated deferred income taxes		28,307			13,109			99,929			49,307			48,584
Interest accrued		180,997			184,664			183,512			217,685			192,283
Deferred fuel costs		57,631			96,439			255,839			166,409			219,639
Obligations under capital leases		2,323			3,880			3,631			3,388			212,496
Pension and other postretirement liabilities		67,419			95,900			44,031			39,862			55,031
System agreement cost equalization		61,040			25,848			80,090			52,160			187,204
Other		423,470			261,986			283,531			277,598			215,202
Total		4,060,572			4,106,321			4,950,699			2,776,249			3,193,997
NON-CURRENT LIABILITIES:
Accumulated deferred income taxes and taxes accrued		8,724,635			8,311,756			8,096,452			8,573,646			7,662,798
Accumulated deferred investment tax credits		263,765			273,696			284,747			292,330			308,395
Obligations under capital leases		32,218			34,541			38,421			42,078			354,233
Other regulatory liabilities		1,295,955			898,614			728,193			539,026			378,862
Decommissioning and asset retirement cost liabilities		3,933,416			3,513,634			3,296,570			3,148,479			2,939,539
Accumulated provisions		115,139			362,226			385,512			395,250			141,315
Pension and other postretirement liabilities		2,320,704			3,725,886			3,133,657			2,175,364			2,241,039
Long-term debt (includes securitization bonds
of $883,013 as of December 31, 2013, $973,480 as of
December 31, 2012, $1,070,556 as of December 31, 2011,
$931,131 as of December 31, 2010,
$838,349 as of December 31, 2009)		12,139,149			11,920,318			10,043,713			11,317,157			10,705,738
Other		583,667			577,910			501,954			618,559			711,334
Total		29,408,648			29,618,581			26,509,219			27,101,889			25,443,253
Commitments and Contingencies
Subsidiaries preferred stock without sinking fund		210,760			186,511			186,511			216,738			217,343
EQUITY:
Common shareholders' equity:
Common stock, $.01 par value, authorized 500,000,000
shares; issued 254,752,788 shares in 2013, 2012, 2011, 2010,
and 2009		2,548			2,548			2,548			2,548			2,548
Paid-in capital		5,368,131			5,357,852			5,360,682			5,367,474			5,370,042
Retained earnings		9,825,053			9,704,591			9,446,960			8,689,401			8,043,122
Accumulated other comprehensive loss		(29,324	)		(293,083	)		(168,452	)		(38,212	)		(75,185	)
Less – treasury stock, at cost (76,381,936 shares in 2013;
76,945,239 shares in 2012; 78,396,988 shares in 2011;
76,006,920 shares in 2010; and 65,634,580 shares in 2009)		5,533,942			5,574,819			5,680,468			5,524,811			4,727,167
Total common shareholders' equity		9,632,466			9,197,089			8,961,270			8,496,400			8,613,360
Subsidiaries preferred stock without sinking fund		94,000			94,000			94,000			94,000			94,000
Total		9,726,466			9,291,089			9,055,270			8,590,400			8,707,360
TOTAL LIABILITIES AND EQUITY	$	43,406,446		$	43,202,502		$	40,701,699		$	38,685,276		$	37,561,953
Certain prior year data has been reclassified to conform with current year presentation.

FINANCIAL RESULTS
2013 CONSOLIDATING BALANCE SHEET (unaudited)
				ENTERGY
				WHOLESALE		PARENT &
In thousands, as of December 31, 2013.	UTILITY			COMMODITIES		OTHER			CONSOLIDATED
ASSETS
CURRENT ASSETS:
Cash and cash equivalents:
Cash	$	119,781		$	9,192	$	1,006		$	129,979
Temporary cash investments		431,436			167,266		10,445			609,147
Total cash and cash equivalents		551,217			176,458		11,451			739,126
Securitization recovery trust account		45,885			-		-			45,885
Notes receivable		-			530,389		(530,389	)		-
Accounts receivable:
Customer		509,176			161,465		-			670,641
Allowance for doubtful accounts		(34,311	)		-		-			(34,311	)
Associated companies		47,887			2,776		(50,663	)		-
Other		184,640			10,353		35			195,028
Accrued unbilled revenues		340,828			-		-			340,828
Total accounts receivable		1,048,220			174,594		(50,628	)		1,172,186
Deferred fuel costs		116,379			-		-			116,379
Accumulated deferred income taxes		195,030			13,915		(33,872	)		175,073
Fuel inventory – at average cost		198,604			10,354		-			208,958
Materials and supplies – at average cost		603,557			311,449		-			915,006
Deferred nuclear refueling outage costs		78,633			113,841		-			192,474
System agreement cost equalization		61,040			-		-			61,040
Prepayments and other		255,907			180,477		(132,820	)		303,564
Total		3,154,472			1,511,477		(736,258	)		3,929,691
OTHER PROPERTY AND INVESTMENTS:
Investment in affiliates – at equity		1,097,270			40,238		(1,097,158	)		40,350
Decommissioning trust funds		2,235,826			2,667,318		-			4,903,144
Non-utility property – at cost (less accumulated depreciation)		182,465			8,189		8,721			199,375
Other		150,015			60,601		-			210,616
Total		3,665,576			2,776,346		(1,088,437	)		5,353,485
PROPERTY, PLANT AND EQUIPMENT:
Electric		38,043,514			4,888,807		3,391			42,935,712
Property under capital lease		941,299			-		-			941,299
Natural gas		366,365			-		-			366,365
Construction work in progress		1,217,138			297,451		268			1,514,857
Nuclear fuel		854,617			712,287		-			1,566,904
Total property, plant and equipment		41,422,933			5,898,545		3,659			47,325,137
Less – accumulated depreciation and amortization		18,199,512			1,243,791		190			19,443,493
Property, plant and equipment – net		23,223,421			4,654,754		3,469			27,881,644
DEFERRED DEBITS AND OTHER ASSETS:
Regulatory assets:
Regulatory asset for income taxes - net		849,718			-		-			849,718
Other regulatory assets (includes securitization property of
$822,218 as of December 31, 2013)		3,893,363			-		-			3,893,363
Deferred fuel costs		172,202			-		-			172,202
Goodwill		374,099			3,073		-			377,172
Accumulated deferred income taxes		9,117			52,894		-			62,011
Other		197,617			698,161		(8,618	)		887,160
Total		5,496,116			754,128		(8,618	)		6,241,626
TOTAL ASSETS	$	35,539,585		$	9,696,705	$	(1,829,844	)	$	43,406,446
Totals may not foot due to rounding.

FINANCIAL RESULTS
2013 CONSOLIDATING BALANCE SHEET (unaudited)
				ENTERGY
				WHOLESALE			PARENT &
In thousands, as of December 31, 2013.	UTILITY			COMMODITIES			OTHER			CONSOLIDATED
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Currently maturing long-term debt	$	438,884		$	18,211		$	-		$	457,095
Notes payable and commercial paper:
Associated companies		-			103,739			(103,739	)		-
Other		2,940			-			1,043,947			1,046,887
Accounts payable:
Associated companies		15,836			28,216			(44,052	)		-
Other		916,616			256,018			679			1,173,313
Customer deposits		370,997			-			-			370,997
Taxes accrued		-			-			191,093			191,093
Accumulated deferred income taxes		97,463			(3	)		(69,153	)		28,307
Interest accrued		156,968			194			23,835			180,997
Deferred fuel costs		57,631			-			-			57,631
Obligations under capital leases		2,323			-			-			2,323
Pension and other postretirement liabilities		58,720			8,699			-			67,419
System agreement cost equalization		61,040			-			-			61,040
Other		141,425			282,045			-			423,470
Total		2,320,843			697,119			1,042,610			4,060,572
NON-CURRENT LIABILITIES:
Accumulated deferred income taxes and taxes accrued		7,340,267			1,266,913			117,455			8,724,635
Accumulated deferred investment tax credits		263,765			-			-			263,765
Obligations under capital leases		32,218			-			-			32,218
Other regulatory liabilities		1,295,955			-			-			1,295,955
Decommissioning and asset retirement cost liabilities		2,235,194			1,698,222			-			3,933,416
Accumulated provisions		110,899			3,191			1,049			115,139
Pension and other postretirement liabilities		1,708,639			612,065			-			2,320,704
Long-term debt (includes securitization bonds
of $883,013 as of December 31, 2013)		10,307,888			76,800			1,754,461			12,139,149
Other		741,376			593,325			(751,034	)		583,667
Total		24,036,201			4,250,516			1,121,931			29,408,648
Commitments and Contingencies
Subsidiaries preferred stock without sinking fund		186,511			24,249			-			210,760
EQUITY:
Common shareholders' equity:
Common stock, $.01 par value, authorized 500,000,000 shares;
issued 254,752,788 shares in 2013		2,161,268			201,094			(2,359,814	)		2,548
Paid-in capital		2,417,670			1,627,856			1,322,605			5,368,131
Retained earnings		4,518,741			2,849,546			2,456,766			9,825,053
Accumulated other comprehensive income (loss)		(75,649	)		46,325			-			(29,324	)
Less – treasury stock, at cost (76,381,936 shares in 2013)		120,000			-			5,413,942			5,533,942
Total common shareholders' equity		8,902,030			4,724,821			(3,994,385	)		9,632,466
Subsidiaries preferred stock without sinking fund		94,000			-			-			94,000
Total		8,996,030			4,724,821			(3,994,385	)		9,726,466
TOTAL LIABILITIES AND EQUITY	$	35,539,585		$	9,696,705		$	(1,829,844	)	$	43,406,446
Totals may not foot due to rounding.

FINANCIAL RESULTS
CONSOLIDATED STATEMENTS OF CASH FLOW (unaudited)
In thousands, for the years ended December 31,	2013			2012			2011			2010			2009
OPERATING ACTIVITIES:
Consolidated net income	$	730,572		$	868,363		$	1,367,372		$	1,270,305		$	1,251,050
Adjustments to reconcile consolidated net income
to net cash flow provided by operating activities:
Depreciation, amortization, and decommissioning, including nuclear fuel amortization		2,012,076			1,771,649			1,745,455			1,705,331			1,458,861
Deferred income taxes, investment tax credits, and non-current taxes accrued		311,789			(26,479	)		(280,029	)		718,987			864,684
Asset impairments and related charges		341,537			355,524			-			-			-
Gain on sale of business		(43,569	)		-			-			(44,173	)		-
Changes in working capital:
Receivables		(180,648	)		(14,202	)		28,091			(99,640	)		116,444
Fuel inventory		4,873			(11,604	)		5,393			(10,665	)		19,291
Accounts payable		94,436			(6,779	)		(131,970	)		216,635			(14,251	)
Prepaid taxes and taxes accrued		(142,626	)		55,484			580,042			(116,988	)		(260,029	)
Interest accrued		(3,667	)		1,152			(34,172	)		17,651			4,974
Deferred fuel costs		(4,824	)		(99,987	)		(55,686	)		8,909			72,314
Other working capital accounts		(66,330	)		(151,989	)		41,875			(160,326	)		(43,391	)
Changes in provisions for estimated losses		(248,205	)		(24,808	)		(11,086	)		265,284			(12,030	)
Changes in other regulatory assets		1,105,622			(398,428	)		(673,244	)		339,408			(415,157	)
Changes in other regulatory liabilities		397,341			170,421			189,167			-			-
Changes in pensions and other postretirement liabilities		(1,433,663	)		644,099			962,461			(80,844	)		71,789
Other		314,505			(192,131	)		(604,852	)		(103,793	)		(181,391	)
Net cash flow provided by operating activities		3,189,219			2,940,285			3,128,817			3,926,081			2,933,158
INVESTING ACTIVITIES:
Construction/capital expenditures		(2,287,593	)		(2,674,650	)		(2,040,027	)		(1,974,286	)		(1,931,245	)
Allowance for equity funds used during construction		69,689			96,131			86,252			59,381			59,545
Nuclear fuel purchases		(517,825	)		(557,960	)		(641,493	)		(407,711	)		(525,474	)
Proceeds from sale/leaseback of nuclear fuel		-			-			-			-			284,997
Proceeds from sale of assets and businesses		147,922			-			6,531			228,171			39,554
Payment for purchase of plant		(17,300	)		(456,356	)		(646,137	)		-			-
Insurance proceeds received for property damages		-			-			-			7,894			53,760
Changes in securitization account		155			4,265			(7,260	)		(29,945	)		(1,036	)
NYPA value sharing payment		(71,736	)		(72,000	)		(72,000	)		(72,000	)		(72,000	)
Payments to storm reserve escrow account		(7,716	)		(8,957	)		(6,425	)		(296,614	)		(6,802	)
Receipts from storm reserve escrow account		260,279			27,884			-			9,925			-
Decrease (increase) in other investments		(82,955	)		15,175			(11,623	)		24,956			100,956
Litigation proceeds for reimbursement of spent nuclear fuel storage costs		21,034			109,105			-			-			-
Proceeds from nuclear decommissioning trust fund sales		2,031,552			2,074,055			1,360,346			2,606,383			2,570,523
Investment in nuclear decommissioning trust funds		(2,147,099	)		(2,196,489	)		(1,475,017	)		(2,730,377	)		(2,667,172	)
Net cash flow used in investing activities		(2,601,593	)		(3,639,797	)		(3,446,853	)		(2,574,223	)		(2,094,394	)
FINANCING ACTIVITIES:
Proceeds from the issuance of:
Long-term debt		3,746,016			3,478,361			2,990,881			3,870,694			2,003,469
Mandatorily redeemable preferred membership units of subsidiary		-			51,000			-			-			-
Preferred stock of subsidiary		24,249			-			-			-			-
Common stock and treasury stock		24,527			62,886			46,185			51,163			28,198
Retirement of long-term debt		(3,814,666	)		(3,130,233	)		(2,437,372	)		(4,178,127	)		(1,843,169	)
Repurchase of common stock		-			-			(234,632	)		(878,576	)		(613,125	)
Redemption of subsidiary common and preferred stock		-			-			(30,308	)		-			(1,847	)
Changes in credit borrowings and commercial paper – net		250,889			687,675			(6,501	)		(8,512	)		(25,000	)
Dividends paid:
Common stock		(593,037	)		(589,209	)		(589,605	)		(603,854	)		(576,956	)
Preferred stock		(18,802	)		(22,329	)		(20,933	)		(20,063	)		(19,958	)
Net cash flow provided by (used in) financing activities		(380,824	)		538,151			(282,285	)		(1,767,275	)		(1,048,388	)
Effect of exchange rates on cash and cash equivalents		(245	)		(508	)		287			338			(1,316	)
Net increase (decrease) in cash and cash equivalents		206,557			(161,869	)		(600,034	)		(415,079	)		(210,940	)
Cash and cash equivalents at beginning of period		532,569			694,438			1,294,472			1,709,551			1,920,491
Cash and cash equivalents at end of period	$	739,126		$	532,569		$	694,438		$	1,294,472		$	1,709,551
Certain prior year data has been reclassified to conform with current year presentation.

FINANCIAL RESULTS
CONSOLIDATED STATEMENTS OF CASH FLOW (unaudited)
$ thousands, for the years ended December 31,	2013		2012			2011			2010			2009
SUPPLEMENTAL DISCLOSURE OF
CASH FLOW INFORMATION:
Cash paid (received) during the period for:
Interest – net of amount capitalized		570,212		546,125			532,271			534,004			576,811
Income taxes		127,735		49,214			(2,042	)		32,144			43,057
Noncash financing activities:
Long-tern debt retired (equity unit notes)		-		-			-			-			(500,000	)
Common stock issued in settlement of equity unit purchase contracts		-		-			-			-			500,000
CASH FLOW INFORMATION BY BUSINESS
						ENTERGY
						WHOLESALE				PARENT &
For the years ended December 31, 2013, 2012, 2011, 2010, and 2009.			UTILITY			COMMODITIES			OTHER			CONSOLIDATED
($ thousands)
2013
Net cash flow provided by operating activities				2,208,089			730,011			251,118			3,189,219
Net cash flow provided by (used in) investing activities				(1,989,855	)		(611,689	)		(51	)		(2,601,593	)
Net cash flow provided by (used in) financing activities				(47,150	)		(82,542	)		(251,132	)		(380,824	)
2012
Net cash flow provided by (used in) operating activities				2,354,454			675,779			(89,948	)		2,940,285
Net cash flow provided by (used in) investing activities				(3,070,785	)		(563,996	)		(5,016	)		(3,639,797	)
Net cash flow provided by (used in) financing activities				736,832			(292,860	)		94,179			538,151
2011
Net cash flow provided by operating activities				2,099,569			756,499			272,749			3,128,817
Net cash flow provided by (used in) investing activities				(2,346,218	)		(1,262,664	)		162,029			(3,446,853	)
Net cash flow provided by (used in) financing activities				(215,304	)		374,484			(441,465	)		(282,285	)
2010
Net cash flow provided by operating activities				2,941,596			629,787			354,698			3,926,081
Net cash flow provided by (used in) investing activities				(2,500,139	)		(399,439	)		325,355			(2,574,223	)
Net cash flow provided by (used in) financing activities				(859,141	)		(230,203	)		(677,930	)		(1,767,274	)
2009
Net cash flow provided by (used in) operating activities				1,586,020			2,626,034			(1,278,896	)		2,933,158
Net cash flow provided by (used in) investing activities				(1,465,824	)		(1,927,120	)		1,298,550			(2,094,394	)
Net cash flow provided by (used in) financing activities				553,107			(701,801	)		(899,694	)		(1,048,388	)
Certain prior year data has been reclassified to conform with current year presentation.
Totals may not foot due to rounding.

FINANCIAL RESULTS
CONSOLIDATED STATEMENTS OF CHANGES IN EQUITY AND COMPREHENSIVE INCOME (unaudited)
($ thousands)				Common Shareholders’ Equity
	Subsidiaries’ Preferred Stock			Common Stock		Treasury Stock			Paid-in Capital			Retained Earnings			Accumulated Other Comprehensive Income (Loss)			Total
Balance at December 31, 2008		94,000			2,482		(4,175,214	)		4,869,303			7,382,719			(112,698	)		8,060,592
Consolidated net income (a)		19,958			-		-			-			1,231,092			-			1,251,050
Other comprehensive income		-			-		-			-			-			43,878			43,878
Common stock repurchases		-			-		(613,125	)		-			-			-			(613,125	)
Common stock issuances in settlement of equity unit purchase contracts		-			66		-			499,934			-			-			500,000
Common stock issuances related to stock plans		-			-		61,172			805			-			-			61,977
Common stock dividends declared		-			-		-			-			(576,913	)		-			(576,913	)
Preferred dividend requirements of subsidiaries (a)		(19,958	)		-		-			-			-			-			(19,958	)
Capital stock and other expenses		-			-		-			-			(141	)		-			(141	)
Adjustment for implementation of new accounting pronouncement		-			-		-			-			6,365			(6,365	)		-
Balance at December 31, 2009		94,000			2,548		(4,727,167	)		5,370,042			8,043,122			(75,185	)		8,707,360
Consolidated net income (a)		20,063			-		-			-			1,250,242			-			1,270,305
Other comprehensive income		-			-		-			-			-			36,973			36,973
Common stock repurchases		-			-		(878,576	)		-			-			-			(878,576	)
Common stock issuances related to stock plans		-			-		80,932			(2,568	)		-			-			78,364
Common stock dividends declared		-			-		-			-			(603,963	)		-			(603,963	)
Preferred dividend requirements of subsidiaries (a)		(20,063	)		-		-			-			-			-			(20,063	)
Balance at December 31, 2010		94,000			2,548		(5,524,811	)		5,367,474			8,689,401			(38,212	)		8,590,400
Consolidated net income (a)		20,933			-		-			-			1,346,439			-			1,367,372
Other comprehensive loss		-			-		-			-			-			(130,240	)		(130,240	)
Common stock repurchases		-			-		(234,632	)		-			-			-			(234,632	)
Common stock issuances related to stock plans		-			-		78,975			(6,792	)		-			-			72,183
Common stock dividends declared		-			-		-			-			(588,880	)		-			(588,880	)
Preferred dividend requirements of subsidiaries (a)		(20,933	)		-		-			-			-			-			(20,933	)
Balance at December 31, 2011		94,000			2,548		(5,680,468	)		5,360,682			9,446,960			(168,452	)		9,055,270
Consolidated net income (a)		21,690			-		-			-			846,673			-			868,363
Other comprehensive loss		-			-		-			-			-			(124,631	)		(124,631	)
Common stock issuances related to stock plans		-			-		105,649			(2,830	)		-			-			102,819
Common stock dividends declared		-			-		-			-			(589,042	)		-			(589,042	)
Preferred dividend requirements of subsidiaries (a)		(21,690	)		-		-			-			-			-			(21,690	)
Balance at December 31, 2012		94,000			2,548		(5,574,819	)		5,357,852			9,704,591			(293,083	)		9,291,089
Consolidated net income (a)		18,670			-		-			-			711,902			-			730,572
Other comprehensive income		-			-		-			-			-			263,759			263,759
Common stock issuances related to stock plans		-			-		40,877			10,279			-			-			51,156
Common stock dividends declared		-			-		-			-			(591,440	)		-			(591,440	)
Preferred dividend requirements of subsidiaries (a)		(18,670	)		-		-			-			-			-			(18,670	)
Balance at December 31, 2013		94,000			2,548		(5,533,942	)		5,368,131			9,825,053			(29,324	)		9,726,466
Certain prior year data has been reclassified to conform with current year presentation.
(a) Consolidated net income and preferred dividend requirements of subsidiaries for 2013, 2012, 2011, 2010 and 2009 include $12.0 million, $15.0 million, $13.3 million, $13.3 million, and $13.3 million respectively,
of preferred dividends on subsidiaries’ preferred stock without sinking fund that is not presented as equity.

FINANCIAL RESULTS
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME
In thousands, for the years ended December 31,	2013			2012			2011			2010			2009
NET INCOME	$	730,572		$	868,363		$	1,367,372		$	1,270,305		$	1,251,050
Other comprehensive income (loss)
Cash flow hedges net unrealized gain (loss)
(net of tax expense (benefit) of ($87,940), ($55,750), $34,411, ($7,088), and $333
for 2013 to 2009, respectively)		(161,682	)		(97,591	)		71,239			(11,685	)		(2,887	)
Pension and other postretirement liabilities
(net of tax expense (benefit) of $220,899, ($61,223), ($131,198), ($14,387), and ($34,415)
for 2013 to 2009, respectively)		302,489			(91,157	)		(223,090	)		(8,527	)		(35,707	)
Net unrealized investment gains
(net of tax expense of $118,878, $61,104, $19,368, $51,130, and $102,845
for 2013 to 2009, respectively)		122,709			63,609			21,254			57,523			82,929
Foreign currency translation
(net of tax expense (benefit) of $131, $275, $192, ($182), and ($246)
for 2013 to 2009, respectively)		243			508			357			(338	)		(457	)
Other comprehensive income (loss)		263,759			(124,631	)		(130,240	)		36,973			43,878
COMPREHENSIVE INCOME		994,331			743,732			1,237,132			1,307,278			1,294,928
Preferred dividend requirements of subsidiaries		18,670			21,690			20,933			20,063			19,958
COMPREHENSIVE INCOME ATTRIBUTABLE TO ENTERGY CORPORATION	$	975,661		$	722,042		$	1,216,199		$	1,287,215		$	1,274,970

CONSOLIDATED CAPITAL EXPENDITURES
HISTORICAL CAPITAL EXPENDITURES
($ millions)	2013		2012			2011		2010		2009
Utility
Maintenance		1,008		868			925		798		805
Other		1,019		1,973			1,121		777		767
Entergy Wholesale Commodities		349		362			712		471		437
Parent & Other		-		(1	)		-		-		(6	)
Total Historical Capital Expenditures		2,376		3,203			2,758		2,046		2,003

PLANNED CAPITAL EXPENDITURES (as of June 2014)
($ millions)	2014		2015		2016
Utility:
Generation		660		490		605
Transmission		540		645		605
Distribution		685		565		580
Other		160		180		150
Total Utility		2,045		1,880		1,940
Entergy Wholesale Commodities		420		380		230
Total Planned Capital Expenditures		2,465		2,260		2,170

ENTERGY CORPORATION SECURITIES DETAIL(a)
ENTERGY CORPORATION LONG-TERM DEBT					CURRENT OR
			MATURITY	FIRST CALL	FIRST CALL	AS OF DECEMBER 31,
CUSIP		RATE	DATE	DATE	PRICE	2013	2012	2011
							($ millions)
	$3.5B Bank Credit Facility	1.96%	03/19 (c)			$ 255	$ 795	$ 1,920
	Commercial Paper (b)	0.84%				1,045	665	-
29364GAE3	3.625% Notes	3.625%	09/15	Now	MW (T+.35%)	550	550	550
29364GAF0	5.125% Notes	5.125%	09/20	Now	MW (T+.40%)	450	450	450
29364GAG8	4.70% Notes	4.7%	01/17	Now	MW (T+.50%)	500	500	-
	Total					$ 2,800	$ 2,960	$ 2,920
(a) On February 16, 2012, Entergy Gulf States Louisiana, L.L.C. sold 500,000 units ($51 million) of Class A preferred, non-voting, membership interest units of Entergy Holdings
Company LLC that carry a 10% annual distribution rate. Distributions are payable quarterly commencing on September 15, 2008 and have a liquidation price of $100 per
unit. The preferred membership interests are callable at the option of Entergy Holdings Company LLC after ten years under the terms of the LLC agreement.  This preferred
membership interest is reflected in the Parent & Other disclosure segment in ‘Other Non-Current Liabilities’ on the balance sheet.
(b) Entergy Corporation has a commercial paper program with a program limit of up to $1.5 billion.
(c) The maturity date was extended to 03/19 in first quarter 2014.

SECURITIES RATINGS (OUTLOOK)
	CORPORATE CREDIT
As of June 2014		MOODY’S	S&P
Entergy Corporation		Baa3 (stable)	BBB (stable)

UTILITY SELECTED DATA
UTILITY QUARTERLY FINANCIAL METRICS
	2013											2012											YTD %
		1	Q	2	Q	3	Q	4	Q	YTD			1	Q	2	Q	3	Q	4	Q	YTD		CHANGE
GAAP MEASURES
As-Reported Net Income ($ millions)		123.5		196.2		348.0		161.2			828.9		62.9		304.2		296.2		279.8			943.0		(12.1	)
Return on Average Invested Capital –
As-Reported (%)(a)		7.2		6.5		6.7		5.9			5.9		7.6		7.9		6.4		6.9			6.9		(14.5	)
Return on Average Common Equity –
As-Reported (%)(a)		12.6		10.9		11.2		9.6			9.6		13.4		13.8		10.5		11.8			11.8		(18.6	)
Debt to Capital Ratio (%)		55.1		55.9		54.9		54.0			54.0		54.4		53.3		53.7		54.9			54.9		(1.6	)
NON-GAAP MEASURES
Operational Earnings ($ millions)		129.8		211.1		363.3		153.7			857.8		68.7		314.1		306.9		290.5			980.1		(12.5	)
Return on Average Invested Capital –
Operational (%)(a)		7.4		6.7		6.9		6.1			6.1		7.7		8.0		6.5		7.1			7.1		(14.1	)
Return on Average Common Equity –
Operational (%)(a)		13.1		11.5		11.8		10.0			10.0		13.5		14.0		10.8		12.3			12.3		(18.7	)
Debt to Capital Ratio,      excluding securitization debt (%)		52.7		53.7		52.7		51.9			51.9		51.5		50.5		51.0		52.4			52.4		(1.0	)
Net Debt to Net Capital Ratio,      excluding securitization debt (%)		52.4		53.3		52.1		50.5			50.5		50.2		50.0		49.4		51.4			51.4		(1.8	)
(a) Rolling twelve months. Totals may not foot due to rounding.

UTILITY ANNUAL FINANCIAL METRICS
	2013		2012		2011		2010		2009
GAAP MEASURES
As-Reported Net Income ($ millions)		828.9		943.0		1,106.5		812.4		691.6
Return on Average Invested Capital – As-Reported (%)		5.9		6.9		8.3		6.9		6.4
Return on Average Common Equity – As-Reported (%)		9.6		11.8		14.8		11.4		10.1
Debt to Capital Ratio (%)		54.0		54.9		54.0		54.3		55.6
NON-GAAP MEASURES
Operational Earnings ($ millions)		857.8		980.1		1,106.5		812.4		691.6
Return on Average Invested Capital – Operational (%)		6.1		7.1		8.3		6.9		6.4
Return on Average Common Equity – Operational (%)		10.0		12.3		14.8		11.4		10.1
Debt to Capital Ratio, excluding securitization debt (%)		51.9		52.4		50.9		51.6		53.2
Net Debt to Net Capital Ratio,  excluding securitization debt (%)		50.5		51.4		49.8		48.9		49.2

UTILITY SECURITIES RATINGS (OUTLOOK)
	MORTGAGE BONDS		PREFERRED STOCK
As of June 2014	MOODY’S	S&P	MOODY’S	S&P
Entergy Arkansas, Inc.	A3 (stable)	A- (stable)	Ba1	BB+
Entergy Gulf States Louisiana, L.L.C.	A2 (stable)	A- (stable)	Baa3	BB+
Entergy Louisiana, LLC	A2 (stable)	A- (stable)	Baa3	BB+
Entergy Mississippi, Inc.	A3 (stable)	A- (stable)	Ba1	BB+
Entergy New Orleans, Inc.	Baa3 (stable)	A- (stable)	B1	BB+
Entergy Texas, Inc.	Baa1 (stable)	A- (stable)	n/a	n/a
System Energy Resources, Inc.	Baa1 (stable)	A- (stable)	n/a	n/a

UTILITY HISTORICAL CAPITAL EXPENDITURES(a)
($ millions)	2013	2012	2011	2010	2009
Entergy Arkansas	489	615	383	291	264
Entergy Gulf States Louisiana	267	284	219	237	274
Entergy Louisiana	711	787	734	428	468
Entergy Mississippi	168	378	166	224	131
Entergy New Orleans	89	86	57	80	62
Entergy Texas	182	181	173	163	188
System Energy Resources	52	450	235	56	91
Other(b)	69	60	79	96	94
Total	2,027	2,841	2,046	1,575	1,572
(a) Historical capital expenditures include storm capital spending.
(b) Corresponds to Entergy Services, Inc., Entergy Operations, Inc., and System Fuels, Inc.

UTILITY SELECTED DATA
UTILITY PLANNED CAPITAL EXPENDITURES  (as of June 2014)
	2014
	Entergy	Entergy Gulf	Entergy	Entergy	Entergy	Entergy	System Energy	Entergy
($ millions)	Arkansas	States Louisiana	Louisiana	Mississippi	New Orleans	Texas	Resources	Services	Utility
Planned construction and capital investment:
Generation	135	100	250	55	-	55	65	-	660
Transmission	130	115	160	35	15	65	-	20	540
Distribution	235	75	145	110	35	85	-	-	685
Other	25	20	20	10	25	10	5	45	160
Total Planned Capital Expenditures	525	310	575	210	75	215	70	65	2,045
Totals may not foot due to rounding.
	2015
	Entergy	Entergy Gulf	Entergy	Entergy	Entergy	Entergy	System Energy	Entergy
($ millions)	Arkansas	States Louisiana	Louisiana	Mississippi	New Orleans	Texas	Resources	Services	Utility
Planned construction and capital investment:
Generation	145	75	170	25	-	25	50	-	490
Transmission	195	130	80	75	20	135	-	10	645
Distribution	160	65	130	100	30	80	-	-	565
Other	15	25	20	20	25	30	5	40	180
Total Planned Capital Expenditures	515	295	400	220	75	270	55	50	1,880
Totals may not foot due to rounding.
	2016
	Entergy	Entergy Gulf	Entergy	Entergy	Entergy	Entergy	System Energy	Entergy
($ millions)	Arkansas	States Louisiana	Louisiana	Mississippi	New Orleans	Texas	Resources	Services	Utility
Planned construction and capital investment:
Generation	180	90	195	35	-	45	55	5	605
Transmission	135	130	75	115	15	135	-	-	605
Distribution	160	75	135	95	25	90	-	-	580
Other	15	20	15	15	25	20	5	35	150
Total Planned Capital Expenditures	490	315	420	260	65	290	60	40	1,940
Totals may not foot due to rounding.
	2014 - 2016
	Entergy	Entergy Gulf	Entergy	Entergy	Entergy	Entergy	System Energy	Entergy
($ millions)	Arkansas	States Louisiana	Louisiana	Mississippi	New Orleans	Texas	Resources	Services	Utility
Total Planned Capital Expenditures	1,530	920	1,395	690	215	775	185	155	5,865

UTILITY FINANCIAL RESULTS
2013 UTILITY CONSOLIDATING INCOME STATEMENT (unaudited)
In thousands, for the year ending December 31, 2013.	EAI			EGSL			ELL			EMI			ENOI			ETI			SERI			OTHER/ ELIMINATIONS(a)			UTILITY
OPERATING REVENUES:
Electric	$	2,190,159		$	1,881,895		$	2,626,935		$	1,334,540		$	525,041		$	1,728,799		$	735,089		$	(2,075,025	)	$	8,947,433
Natural gas		-			59,238			-			-			95,115			-			-			-		$	154,353
Total		2,190,159			1,941,133			2,626,935			1,334,540			620,156			1,728,799			735,089			(2,075,025	)	$	9,101,786
OPERATING EXPENSES:
Operation and maintenance:
Fuel, fuel-related expenses, and gas purchased for resale		426,316			286,625			570,956			328,934			116,715			207,310			103,358			(3,465	)	$	2,036,749
Purchased power		473,326			731,611			850,998			375,745			253,202			857,512			-			(2,046,751	)	$	1,495,643
Nuclear refueling outage expenses		40,499			20,345			34,566			-			-			-			29,551			(1	)	$	124,960
Asset impairments and related charges		-			-			-			-			-			-			-			9,411		$	9,411
Other operation and maintenance		592,892			398,589			480,166			261,832			136,003			253,786			174,772			(34,146	)	$	2,263,894
Decommissioning		43,058			15,908			21,612			-			-			-			35,472			762		$	116,812
Taxes other than income taxes		89,471			80,307			74,241			83,630			48,659			63,823			25,537			4,301		$	469,969
Depreciation and amortization		230,512			150,929			242,787			108,714			37,717			94,744			176,387			(759	)	$	1,041,031
Other regulatory charges (credits) – net		(10,975	)		9,482			(3,785	)		(14,545	)		996			77,491			(13,068	)		1		$	45,597
Total		1,885,099			1,693,796			2,271,541			1,144,310			593,292			1,554,666			532,009			(2,070,647	)	$	7,604,066
OPERATING INCOME		305,060			247,337			355,394			190,230			26,864			174,133			203,080			(4,378	)	$	1,497,720
OTHER INCOME:
Allowance for equity funds used during construction		10,913			8,062			31,544			2,182			920			4,647			7,784			1		$	66,053
Interest and investment income		30,148			52,953			91,599			817			89			1,369			9,844			(95	)	$	186,724
Miscellaneous – net		(4,275	)		(11,567	)		(3,990	)		(3,821	)		(1,401	)		(3,328	)		(804	)		(6	)	$	(29,192	)
Total		36,786			49,448			119,153			(822	)		(392	)		2,688			16,824			(100	)	$	223,585
INTEREST EXPENSE:
Interest expense		91,318			81,118			153,529			59,031			13,675			92,156			38,173			5,673		$	534,673
Allowance for borrowed funds used during construction		(3,207	)		(2,814	)		(13,323	)		(1,539	)		(505	)		(3,324	)		(786	)		(2	)	$	(25,500	)
Total		88,111			78,304			140,206			57,492			13,170			88,832			37,387			5,671		$	509,173
INCOME BEFORE INCOME TAXES		253,735			218,481			334,341			131,916			13,302			87,989			182,517			(10,149	)	$	1,212,132
Income taxes		91,787			56,819			81,877			49,757			1,619			30,108			68,853			(14,903	)	$	365,917
CONSOLIDATED NET INCOME		161,948			161,662			252,464			82,159			11,683			57,881			113,664			4,754		$	846,215
Preferred dividend requirements and other		6,873			825			6,950			2,828			965			-			-			(1,112	)	$	17,329
EARNINGS APPLICABLE TO
COMMON STOCK/EQUITY	$	155,075		$	160,837		$	245,514		$	79,331		$	10,718		$	57,881		$	113,664		$	5,866		$	828,886
(a) Reflects other Entergy subsidiaries, including EGS Holdings, Inc. and Entergy Louisiana Holdings, Inc., the respective parent companies of EGSL and ELL, as well as Entergy Services, Inc. and the elimination of intercompany
transactions.
Totals may not foot due to rounding.

UTILITY FINANCIAL RESULTS
2013 UTILITY CONSOLIDATING BALANCE SHEET (unaudited)
In thousands, as of December 31, 2013.	EAI			EGSL			ELL			EMI			ENOI			ETI			SERI		OTHER/ ELIMINATIONS(a)			UTILITY
ASSETS
CURRENT ASSETS:
Cash and cash equivalents:
Cash		4,181			1,739			427			22			317			2,432			62,561	$	48,102			119,781
Temporary cash investments		122,841			13,842			123,580			9			33,172			44,056			64,581		29,355			431,436
Total cash and cash equivalents		127,022			15,581			124,007			31			33,489			46,488			127,142		77,457			551,217
Securitization recovery trust account		3,835			-			4,539			-			-			37,511			-		-			45,885
Accounts receivable:
Customer		102,328			69,648			144,836			76,534			38,872			76,957			-		1			509,176
Allowance for doubtful accounts		(30,113	)		(909	)		(965	)		(906	)		(974	)		(443	)		-		(1	)		(34,311	)
Associated companies		68,875			107,723			87,820			13,794			32,273			76,494			104,419		(443,511	)		47,887
Other		94,256			22,945			21,420			9,117			2,667			10,897			6,400		16,938			184,640
Accrued unbilled revenues		82,298			58,867			93,073			44,777			18,745			43,067			-		1			340,828
Total account receivable		317,644			258,274			346,184			143,316			91,583			206,972			110,819		(426,572	)		1,048,220
Deferred fuel costs		68,696			9,625			-			38,057			-			-			-		1			116,379
Accumulated deferred income taxes		33,556			-			100,022			-			12,018			-			-		49,434			195,030
Fuel inventory – at average cost		41,504			26,555			23,311			48,899			2,999			55,335			-		1			198,604
Materials and supplies – at average cost		152,429			122,909			156,487			40,849			11,696			34,068			85,118		1			603,557
Deferred nuclear refueling outage costs		31,135			25,975			13,670			-			-			-			7,853		-			78,633
System agreement cost equalization		30,000			-			-			15,000			-			16,040			-		-			61,040
Prepaid taxes		-			22,008			184,503			-			-			55,635			-		(262,146	)		-
Gas hedge contracts		-			2,238			2,889			-			-			-			-		(5,127	)		-
Prepayments and other		58,911			12,452			15,223			4,813			4,178			34,458			1,727		124,145			255,907
Total		864,732			495,617			970,835			290,965			155,963			486,507			332,659		(442,806	)		3,154,472
OTHER PROPERTY AND INVESTMENTS:
Investment in affiliates – at equity		-			289,664			807,423			-			-			687			-		(504	)		1,097,270
Decommissioning trust funds		710,913			573,744			347,274			-			-			-			603,896		(1	)		2,235,826
Non-utility property – at cost (less accumulated depreciation)		1,664			174,134			396			4,670			1,016			376			-		209			182,465
Storm reserve escrow account		-			21,538			-			-			10,513			-			-		(32,051	)		-
Escrow accounts		-			-			-			51,795			-			-			-		(51,795	)		-
Other		29,181			14,145			-			-			-			18,161			-		88,528			150,015
Total		741,758			1,073,225			1,155,093			56,465			11,529			19,224			603,896		4,386			3,665,576
PROPERTY, PLANT AND EQUIPMENT
Electric		8,798,458			7,400,689			8,799,393			3,875,737			889,629			3,616,061			4,124,647		538,900			38,043,514
Property under capital lease		1,064			-			331,895			5,329			-			-			570,872		32,139			941,299
Natural gas		-			143,902			-			-			222,463			-			-		-			366,365
Construction work in progress		209,036			105,314			672,883			37,316			29,312			94,743			29,061		39,473			1,217,138
Nuclear fuel		321,901			196,508			147,385			-			-			-			188,824		(1	)		854,617
Total property, plant and equipment		9,330,459			7,846,413			9,951,556			3,918,382			1,141,404			3,710,804			4,913,404		610,511			41,422,933
Less – accumulated depreciation and amortization		4,034,880			4,071,762			3,763,234			1,413,484			566,948			1,387,303			2,699,263		262,638			18,199,512
Property, plant and equipment – net		5,295,579			3,774,651			6,188,322			2,504,898			574,456			2,323,501			2,214,141		347,873			23,223,421
DEFERRED DEBITS AND OTHER ASSETS:
Regulatory assets:
Regulatory asset for income taxes - net		73,864			165,456			309,617			58,716			-			129,069			115,492		(2,496	)		849,718
Other regulatory assets (includes securitization property of
$822,218 as of December 31, 2013)		1,014,392			321,466			715,503			318,462			137,191			919,234			261,740		205,375			3,893,363
Deferred fuel costs		-			100,124			67,998			-			4,080			-			-		-			172,202
Long-term receivables  - associated companies		-			-			-			-			-			27,900			-		(27,900	)		-
Goodwill		-			-			-			-			-			-			-		374,099			374,099
Accumulated deferred income taxes		-			-			-			-			-			-			-		9,117			9,117
Other		44,565			12,049			43,025			20,819			5,577			16,425			15,996		39,161			197,617
Total		1,132,821			599,095			1,136,143			397,997			146,848			1,092,628			393,228		597,356			5,496,116
TOTAL ASSETS		8,034,890			5,942,588			9,450,393			3,250,325			888,796			3,921,860			3,543,924		506,809			35,539,585
(a) Reflects other Entergy subsidiaries, including EGS Holdings, Inc. and Entergy Louisiana Holdings, Inc., the respective parent companies of EGSL and ELL, as well as Entergy Services, Inc. and the elimination of
intercompany transactions.
Totals may not foot due to rounding.

UTILITY FINANCIAL RESULTS
2013 UTILITY CONSOLIDATING BALANCE SHEET (unaudited)
In thousands, as of December 31, 2013.	EAI		EGSL			ELL			EMI			ENOI		ETI		SERI		OTHER/ ELIMINATIONS(a)			UTILITY
LIABILITIES AND EQUITY
CURRENT LIABILITIES:
Currently maturing long-term debt	$	70,000	$	-		$	320,231		$	-		$	-	$	-	$	48,653	$	-		$	438,884
Notes payable and commercial paper:
Other		-		-			2,923			-			-		-		-		17		$	2,940
Accounts payable:
Associated companies		149,802		95,853			83,655			74,144			36,193		112,309		12,778		(548,898	)	$	15,836
Other		228,160		103,314			162,507			52,129			27,840		73,682		31,862		237,122		$	916,616
Customer deposits		86,512		51,839			90,393			74,211			22,959		38,721		-		6,362		$	370,997
Taxes accrued		9,979		-			-			53,247			1,509		-		11,121		(75,856	)	$	-
Accumulated deferred income taxes		9,231		36,330			338			15,413			-		33,847		2,310		(6	)	$	97,463
Interest accrued		22,036		25,808			42,072			20,383			3,598		31,246		11,825		-		$	156,968
Deferred fuel costs		-		-			30,392			-			23,145		4,093		-		1		$	57,631
Obligations under capital leases		-		-			-			-			-		-		-		2,323		$	2,323
Pension and other postretirement liabilities		-		9,065			10,255			-			-		786		-		38,614		$	58,720
System agreement cost equalization		-		15,000			17,000			-			17,040		12,000		-		-		$	61,040
Other		55,656		19,032			19,443			19,021			4,387		23,490		2,312		(1,916	)	$	141,425
Total		631,376		356,241			779,209			308,548			136,671		330,174		120,861		(342,237	)		2,320,843
NON-CURRENT LIABILITIES:
Accumulated deferred income taxes and taxes accrued		1,906,562		1,512,547			1,275,584			746,939			183,636		1,022,955		737,973		(45,929	)	$	7,340,267
Accumulated deferred investment tax credits		38,958		75,295			67,347			8,530			1,082		16,147		54,786		1,620		$	263,765
Obligations under capital leases		-		-			-			4,185			-		-		-		28,033		$	32,218
Regulatory liability for income taxes - net		-		-			-			-			2,495		-		-		(2,495	)	$	-
Other regulatory liabilities		219,370		159,429			533,247			2,509			26,361		5,194		349,846		(1	)	$	1,295,955
Decommissioning and asset retirement cost liabilities		723,771		403,084			479,086			6,401			2,347		4,349		616,157		(1	)	$	2,235,194
Accumulated provisions		5,746		37,146			7,733			35,674			15,000		9,079		-		521		$	110,899
Pension and other postretirement liabilities		319,211		274,315			358,017			66,722			32,497		51,253		79,411		527,213		$	1,708,639
Long-term debt (includes securitization bonds
of $883,013 as of December 31, 2013)		2,335,802		1,527,465			2,899,285			1,053,670			225,944		1,556,939		708,783		-		$	10,307,888
Long-term payables - associated companies		-		27,900			-			-			-		-		-		(27,900	)	$	-
Gas system rebuild insurance proceeds		-		-			-			-			32,760		-		-		(32,760	)	$	-
Other		18,026		108,189			75,233			15,189			3,940		38,743		-		482,056		$	741,376
Total		5,567,446		4,125,370			5,695,532			1,939,819			526,062		2,704,659		2,546,956		930,357			24,036,201
Commitments and Contingencies
Subsidiaries preferred stock without sinking fund		116,350		-			-			50,381			19,780		-		-		-		$	186,511
EQUITY:
Common stock or members’ equity		470		1,479,179			2,885,287			199,326			33,744		49,452		789,350		(3,275,540	)	$	2,161,268
Paid-in capital/capital stock expense and other		588,471		-			-			(690	)		36,294		481,994		-		1,311,601		$	2,417,670
Retained earnings		1,130,777		-			-			752,941			136,245		355,581		86,757		2,056,440		$	4,518,741
Accumulated other comprehensive income (loss)		-		(28,202	)		(9,635	)		-			-		-		-		(37,812	)	$	(75,649	)
Less – treasury stock, at cost		-		-			-			-			-		-		-		120,000		$	120,000
Total		1,719,718		1,450,977			2,875,652			951,577			206,283		887,027		876,107		(65,311	)		8,902,030
Preferred membership interests without sinking fund		-		10,000			100,000			-			-		-		-		(16,000	)	$	94,000
Total		1,719,718		1,460,977			2,975,652			951,577			206,283		887,027		876,107		(81,311	)		8,996,030
TOTAL LIABILITIES AND EQUITY	$	8,034,890	$	5,942,588		$	9,450,393		$	3,250,325		$	888,796	$	3,921,860	$	3,543,924	$	506,809		$	35,539,585
(a) Reflects other Entergy subsidiaries, including EGS Holdings, Inc. and Entergy Louisiana Holdings, Inc., the respective parent companies of EGSL and ELL, as well as Entergy Services, Inc. and the elimination of
intercompany transactions.
Totals may not foot due to rounding.

UTILITY FINANCIAL RESULTS
UTILITY SELECTED ANNUAL FINANCIAL METRICS
	2013			2012			2011		2010		2009
ENTERGY ARKANSAS, INC.
As-Reported Earnings ($ millions)		155.1			145.5			158.0		165.7		60.0
Less Special Items ($ millions)		(2.8	)		(13.0	)		-		-		-
Operational Earnings ($ millions)		157.9			158.5			158.0		165.7		60.0
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		9.4			9.6			11.1		11.8		4.3
Return on Average Invested Capital – As-Reported (%)		5.3			5.5			6.2		6.7		3.7
Cash Flow Interest Coverage (# times)		5.6			7.3			7.9		6.7		5.3
Debt to Capital Ratio (%)		56.7			56.0			55.0		55.9		54.0
Total Debt ($ millions)		2,407			2,162			1,911		1,928		1,793
Total Preferred ($ millions)		116			116			116		116		116
Total Equity ($ millions)		1,720			1,580			1,444		1,404		1,412
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		9.6			10.5			11.1		11.8		4.3
Return on Average Invested Capital – Operational (%)		5.5			6.0			6.4		6.8		3.7
Total Debt, excluding securitization debt ($ millions)		2,318			2,060			1,797		1,804		1,793
Debt to Capital Ratio, excluding securitization debt (%)		55.8			54.8			53.5		54.3		54.0
Net Debt to Net Capital Ratio, excluding securitization debt (%)		54.4			54.4			53.2		52.8		52.8
ENTERGY GULF STATES LOUISIANA, L.L.C.
As-Reported Earnings ($ millions)		160.8			158.2			200.8		173.5		152.5
Less Special Items ($ millions)		(5.2	)		(4.6	)		-		-		-
Operational Earnings ($ millions)		166.0			162.8			200.8		173.5		152.5
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		11.4			11.7			14.5		12.1		11.3
Return on Average Invested Capital – As-Reported (%)		7.1			7.2			8.5		7.5		6.7
Cash Flow Interest Coverage (# times)		6.5			5.3			7.0		8.4		3.1
Debt to Capital Ratio (%)		51.1			52.3			53.6		52.0		55.8
Total Debt ($ millions)		1,528			1,517			1,542		1,584		1,783
Total Preferred ($ millions)		10			10			10		10		10
Total Equity ($ millions)		1,451			1,373			1,324		1,454		1,403
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		11.8			12.1			14.5		12.1		11.3
Return on Average Invested Capital – Operational (%)		7.3			7.4			8.5		7.7		7.8
Total Debt, excluding assumption debt ($ millions)		1,528			1,517			1,542		1,584		1,615
Debt to Capital Ratio, excluding assumption debt (%)		51.1			52.3			53.6		52.0		53.3
Net Debt to Net Capital Ratio, excluding assumption debt (%)		50.9			51.7			53.2		49.4		51.0
Certain years were restated to reflect a correction of regulatory asset for
income taxes determined in first quarter 2012.
ENTERGY LOUISIANA, LLC
As-Reported Earnings ($ millions)		245.5			274.1			467.0		224.5		225.9
Less Special Items ($ millions)		(3.8	)		(6.6	)		-		-		-
Operational Earnings ($ millions)		249.3			280.7			467.0		224.5		225.9
GAAP MEASURES
Return on Average Members’ Equity – As-Reported (%)		8.4			10.1			20.7		11.7		13.2
Return on Average Invested Capital – As-Reported (%)		5.6			6.5			12.1		7.6		8.2
Cash Flow Interest Coverage (# times)		5.7			4.9			5.9		10.4		2.3
Debt to Capital Ratio (%)		52.0			48.4			47.2		46.1		49.9
Total Debt ($ millions)		3,222			2,881			2,297		1,830		1,902
Total Preferred ($ millions)		100			100			100		100		100
Total Equity ($ millions)		2,876			2,971			2,465		2,037		1,812
NON-GAAP MEASURES
Return on Average Members’ Equity – Operational (%)		8.5			10.3			20.7		11.7		13.2
Return on Average Invested Capital – Operational (%)		5.8			6.9			12.4		7.6		8.2
Total Debt, excluding securitization debt ($ millions)		3,058			2,699			2,090		1,830		1,902
Debt to Capital Ratio, excluding securitization debt (%)		50.7			46.8			44.9		46.1		49.9
Net Debt to Net Capital Ratio, excluding securitization debt (%)		49.6			46.5			44.9		44.4		47.8

UTILITY FINANCIAL RESULTS
UTILITY SELECTED ANNUAL FINANCIAL METRICS (CONTINUED)
	2013			2012			2011		2010		2009
ENTERGY MISSISSIPPI, INC.
As-Reported Earnings ($ millions)		79.3			43.9			105.9		82.5		76.5
Less Special Items ($ millions)		(5.4	)		(7.5	)		-		-		-
Operational Earnings ($ millions)		84.7			51.4			105.9		82.5		76.5
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		8.7			5.1			13.5		11.6		11.2
Return on Average Invested Capital – As-Reported (%)		5.6			4.1			8.0		7.3		7.3
Cash Flow Interest Coverage (# times)		4.8			4.7			3.1		3.3		5.4
Debt to Capital Ratio (%)		51.4			55.9			51.2		51.7		53.4
Total Debt ($ millions)		1,059			1,178			931		839		852
Total Preferred ($ millions)		50			50			50		50		50
Total Equity ($ millions)		952			880			836		733		694
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		9.3			6.0			13.5		11.6		11.2
Return on Average Invested Capital – Operational (%)		5.9			4.5			8.0		7.3		7.3
Net Debt to Net Capital Ratio (%)		51.4			54.7			51.2		51.7		50.5
ENTERGY NEW ORLEANS, INC.
As-Reported Earnings ($ millions)		10.7			16.1			35.0		30.1		29.5
Less Special Items ($ millions)		(2.9	)		(0.9	)		-		-		-
Operational Earnings ($ millions)		13.6			17.0			35.0		30.1		29.5
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		5.3			8.5			19.0		15.3		14.3
Return on Average Invested Capital – As-Reported (%)		4.6			6.1			11.5		8.9		8.2
Cash Flow Interest Coverage (# times)		7.5			5.7			5.1		4.9		9.8
Debt to Capital Ratio (%)		50.0			47.7			45.3		44.6		54.8
Total Debt ($ millions)		226			196			167		167		272
Total Preferred ($ millions)		20			20			20		20		20
Total Equity ($ millions)		206			196			181		188		205
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		6.8			9.0			19.0		15.3		14.3
Return on Average Invested Capital – Operational (%)		5.2			6.3			11.5		8.9		8.2
Net Debt to Net Capital Ratio (%)		46.0			46.5			43.8		35.1		26.5
ENTERGY TEXAS, INC.
As-Reported Net Income ($ millions)		57.9			42.0			80.8		66.2		63.8
Less Special Items ($ millions)		(8.8	)		(4.6	)		-		-		-
Operational Net Income ($ millions)		66.7			46.6			80.8		66.2		63.8
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		6.6			4.8			9.4		7.9		7.3
Return on Average Invested Capital – As-Reported (%)		4.6			3.9			5.4		4.9		5.4
Cash Flow Interest Coverage (# times)		3.7			3.9			3.6		1.4		3.7
Debt to Capital Ratio (%)		63.7			65.4			65.1		66.8		66.3
Total Debt ($ millions)		1,557			1,618			1,677		1,659		1,658
Total Preferred ($ millions)		-			-			-		-		-
Total Equity ($ millions)		887			854			899		824		844
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		7.7			5.3			9.4		7.9		7.3
Return on Average Invested Capital – Operational (%)		6.8			5.5			7.8		7.3		7.1
Total Debt, excluding securitization debt ($ millions)		928			928			927		852		820
Debt to Capital Ratio, excluding securitization debt (%)		51.1			52.2			50.8		50.8		49.3
Net Debt to Net Capital Ratio, excluding securitization debt (%)		49.8			50.4			48.9		49.8		42.3

UTILITY FINANCIAL RESULTS
UTILITY SELECTED ANNUAL FINANCIAL METRICS (CONTINUED)
	2013		2012		2011		2010		2009
SYSTEM ENERGY RESOURCES, INC.
As-Reported Net Income ($ millions)		113.7		111.9		64.2		82.6		48.9
Less Special Items ($ millions)		-		-		-		-		-
Operational Net Income ($ millions)		113.7		111.9		64.2		82.6		48.9
GAAP MEASURES
Return on Average Common Equity – As-Reported (%)		13.3		13.7		8.0		10.1		5.8
Return on Average Invested Capital – As-Reported (%)		8.3		8.4		5.6		6.8		4.4
Cash Flow Interest Coverage (# times)		8.3		11.7		11.4		5.9		10.7
Debt to Capital Ratio (%)		46.4		49.7		48.3		51.7		49.7
Total Debt ($ millions)		757		824		747		869		820
Total Preferred ($ millions)		-		-		-		-		-
Total Equity ($ millions)		876		833		801		812		830
NON-GAAP MEASURES
Return on Average Common Equity – Operational (%)		13.3		13.7		8.0		10.1		5.8
Return on Average Invested Capital – Operational (%)		8.3		8.4		5.6		6.8		4.4
Net Debt to Net Capital Ratio (%)		41.8		47.1		41.2		42.7		40.1

UTILITY SECURITIES DETAIL
UTILITY LONG-TERM DEBT AND PREFERRED STOCK
ENTERGY ARKANSAS, INC.
BONDS:				MATURITY	FIRST CALL	CURRENT OR	AS OF DECEMBER 31,
CUSIP		TYPE*	RATE	DATE	DATE	FIRST CALL PRICE	2013	2012	2011
								(in millions)
29364DAN0	5.40% Series	M	5.4%	08/13			$               -	$ 300	$      300
472712ER5	4.6% Series – Jefferson County(c)	G(b)	4.6%	2017			-	55	55
472712ES3	1.55% Series – Jefferson County(c)	G(b)	1.55%	2017	Non-Call Life		55
29364DAH3	5.0% Series(d)	M	5.0%	07/18	Now	100%	115	115	115
29364DAQ3	3.75% Series	M	3.75%	02/21	Now	MW (T + .20%)	350	350	350
29364DAR1	3.05% Series	M	3.05%	06/23	Now	MW (T + .20%)	250	-	-
453424BP7	5.0% Series – Independence County(c)	G(b)	5.0%	2021			-	45	45
453424BT9	2.38% Series – Independence County(c)	G(b)	2.38%	2021	Non-Call Life		45
29364DAL4	5.66% Series	M	5.66%	02/25	Now	MW (T + .20%)	175	175	175
29364DAJ9	5.9% Series	M	5.9%	06/33	Now	100%	100	100	100
29364DAK6	6.38% Series	M	6.38%	11/34	Now	100%	60	60	60
29364D779	5.75% Series	M	5.75%	11/40	11/1/15	100%	225	225	225
29364D761	4.90% Series	M	4.9%	12/52	12/1/17	100%	200	200	-
29364D753	4.75% Series	M	4.75%	06/63	6/1/18	100%	125	-	-
	Total bonds						1,700	1,625	1,425
OTHER LONG-TERM DEBT:
	9% Series H – Variable Interest Entity Note Payable		9.00%	06/13			-	30	30
	5.69% Series I – Variable Interest Entity Note Payable		5.69%	07/14			70	70	70
	3.23% Series J – Variable Interest Entity Note Payable		3.23%	07/16			55	55	55
	2.62% Series K – Variable Interest Entity Note Payable		2.62%	12/17			60	60	-
29365YAA1	2.30% Series Senior Secured – Securitization Bond		2.30%	08/21			89	102	114
	Long-Term United States Department of Energy Obligation(e)						181	181	181
	Term Loan(f)		1.13%	01/15			250
	Unamortized Premium and Discount – Net						(1)	(1)	(1)
	Other						2	2	2
TOTAL LONG-TERM DEBT(f)							2,406	2,124	1,876
Less Amount Due Within One Year							70	330	-
Long-Term Debt Excluding Amount Due Within One Year							$ 2,336	$ 1,794	$ 1,876
Fair Value of Long-Term Debt(a)							$ 2,143	$ 1,876	$ 1,756
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate							4.0%	4.9%	5.0%
(a) The fair value excludes long-term DOE obligations of $181 million at Entergy Arkansas and includes debt due within one year. Fair values are classified as Level 2 in the fair value hierarchy
(see pgs. 196 - 203 of 2013 10-K) and are based on prices derived from inputs such as benchmark yields and reported trades.
(b) Consists of pollution control revenue bonds and environmental revenue bonds.
(c) The bonds are secured by a series of collateral first mortgage bonds.
(d) The bonds were called in their entirety at par on 4/16/14.
(e) Pursuant to the Nuclear Waste Policy Act of 1982, Entergy’s nuclear owner/licensee subsidiaries have contracts with the DOE for spent nuclear fuel disposal service. The contracts include a one-time fee
for generation prior to April 7, 1983. Entergy Arkansas is the only Entergy company that generated electric power with nuclear fuel prior to that date and includes the one-time fee,
plus accrued interest, in long-term debt.
(f) Term loan was called in its entirety at par on 3/19/14.
Totals may not foot due to rounding.

						SHARES
						AUTHORIZED AND OUTSTANDING												CALL PRICE PER SHARE
PREFERRED STOCK:						AS OF DECEMBER 31,						AS OF DECEMBER 31,						AS OF DECEMBER 31,
CUSIP			RATE			2013		2012		2011		2013		2012		2011		2013
		Without sinking fund:												(in millions)
		Cumulative, $100 par value:
	29364D209	4.32% Series		4.32	%		70,000		70,000		70,000	$	7	$	7	$	7	$	103.65
	29364D506	4.72% Series		4.72	%		93,500		93,500		93,500		9		9		9		107.00
	29364D308	4.56% Series		4.56	%		75,000		75,000		75,000		8		8		8		102.83
	29364D407	4.56% 1965 Series		4.56	%		75,000		75,000		75,000		8		8		8		102.50
	29364D605	6.08% Series		6.08	%		100,000		100,000		100,000		10		10		10		102.83
		Cumulative, $25 par value:
	29364D787	6.45% Series(a)		6.45	%		3,000,000		3,000,000		3,000,000		75		75		75		25
		Total without sinking fund					3,413,500		3,413,500		3,413,500	$	116	$	116	$	116
(a) Series is callable at par.
Totals may not foot due to rounding.

UTILITY LONG-TERM DEBT AND PREFERRED STOCK
ENTERGY GULF STATES LOUISIANA, L.L.C.
BONDS:				MATURITY	FIRST CALL	CURRENT OR	AS OF DECEMBER 31,
CUSIP		TYPE*	RATE	DATE	DATE	FIRST CALL PRICE	2013	2012	2011
								(in millions)
546398K23	2.875% Series – Louisiana Public Facilities Authority	G(b,c)	2.875%	2015	Non-Call Life		32	32	32
952789AZ8	5.8% Series – West Feliciana Parish	G(b,c)	5.8%	2016			-	-	11
29365PAN2	6.00% Series	M	6.0%	05/18	Now	MW (T + .40%)	375	375	375
29365PAQ5	3.95% Series	M	3.95%	10/20	Now	MW (T +. 25%)	250	250	250
29365PAP7	5.59% Series	M	5.59%	10/24	Now	MW (T + .40%)	300	300	300
546398J90	5.0% Series – Louisiana Public Facilities Authority	G(b,c)	5.0%	2028	9/1/15	100%	84	84	84
29364LAL6	6.2% Series	M	6.2%	07/33	Now	100%	240	240	240
29364LAT9	6.18% Series	M	6.18%	03/35	Now	100%	85	85	85
	Total bonds						1,366	1,366	1,377
OTHER LONG-TERM DEBT:
	5.41% Series O – Variable Interest Entity Note Payable		5.41%	07/12			-	-	60
	5.56% Series N – Variable Interest Entity Note Payable		5.56%	05/13			-	75	75
	3.25% Series Q – Variable Interest Entity Note Payable		3.25%	07/17			75	75	-
	3.38% Series R – Variable Interest Entity Note Payable		3.38%	08/20			70	-	-
	Credit Facility – weighted average rate 1.38%		1.38%	06/16			15	-	29
	Unamortized Premium and Discount – Net						(2)	(2)	(2)
	Other						4	4	4
TOTAL LONG-TERM DEBT							1,527	1,517	1,542
Less Amount Due Within One Year							-	75	60
Long-Term Debt Excluding Amount Due Within One Year							$ 1,527	$ 1,442	$ 1,482
Fair Value of Long-Term Debt(a)							$ 1,631	$ 1,669	$ 1,642
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate							5.2%	5.3%	5.4%
(a) The fair value includes debt due within one year. Fair values are classified as Level 2 in the fair value hierarchy
(see pgs. 196 - 203 of 2013 10-K) and are based on prices derived from inputs such as benchmark yields and reported trades.
(b) Consists of pollution control revenue bonds and environmental revenue bonds.
(c) The bonds are secured by a series of collateral first mortgage bonds.
Totals may not foot due to rounding.

						SHARES/UNITS												CALL PRICE
						AUTHORIZED AND OUTSTANDING												PER SHARE/UNIT
PREFERRED MEMBERSHIP INTERESTS:						AS OF DECEMBER 31,						AS OF DECEMBER 31,						AS OF DECEMBER 31,
CUSIP			RATE			2013		2012		2011		2013		2012		2011		2013
		Without sinking fund:												(in millions)
		Cumulative, $100 liquidation value:
	29365P201	8.25% Series(a)		8.25	%		100,000		100,000		100,000	$	10	$	10	$	10		-
		Authorized 6,000,000 shares, $100 par value, cumulative
		Total without sinking fund					100,000		100,000		100,000	$	10	$	10	$	10
(a) Series is callable at par on and after December 15, 2015.
Totals may not foot due to rounding.

UTILITY LONG-TERM DEBT AND PREFERRED STOCK
ENTERGY LOUISIANA, LLC
BONDS:				MATURITY	FIRST CALL	CURRENT OR	AS OF DECEMBER 31,
CUSIP		TYPE*	RATE	DATE	DATE	FIRST CALL PRICE	2013	2012	2011
								(in millions)
29364WAJ7	6.50% Series	M	6.5%	09/18	Now	MW (T + .40%)	$ 300	$ 300	$      300
29364WAN8	4.8% Series	M	4.8%	05/21	Now	MW (T + .25%)	200	200	200
29364WAS7	4.05% Series	M	4.05%	09/23	Now	MW (T + .20%)	325	-	-
29364WAK4	5.40% Series	M	5.4%	11/24	Now	MW (T + .35%)	400	400	400
29364WAM0	4.44% Series	M	4.44%	01/26	Now	MW (T + .30%)	250	250	250
546398J82	5.0% Series – Louisiana Public Facilities Authority	G(b,c)	5.0%	2030	12/1/15	100%	115	115	115
29364WAB4	6.4% Series	M	6.4%	10/34	Now	100%	70	70	70
29364WAF5	6.3% Series	M	6.3%	09/35	Now	100%	100	100	100
29364W306	6.0% Series	M	6.0%	03/40	3/15/15	100%	150	150	150
29364W405	5.875% Series	M	5.875%	06/41	11/23/15	100%	150	150	150
29364WAP3	1.875% Series	M	1.875%	12/14	Now	MW (T + .25%)	250	250	-
29364W504	5.25% Series	M	5.25%	07/52	7/1/17	100%	200	200	-
29364W603	4.7% Series	M	4.7%	06/63	6/1/18	100%	100	-	-
29364WAR9	3.30% Series	M	3.3%	12/22	Now	MW (T + .25%)	200	200	-
	Total bonds						2,810	2,385	1,735
OTHER LONG-TERM DEBT:
	Waterford 3 Lease Obligation 7.45%		7.45%				149	163	188
	Bank Credit Facility  –  weighted average rate 1.67%(d,e)		1.67%	03/19				-	50
	5.69% Series E – Variable Interest Entity Note Payable		5.69%	07/14			50	50	50
	3.30% Series F – Variable Interest Entity Note Payable		3.30%	03/16			20	20	20
	3.25% Series G – Variable Interest Entity Note Payable		3.25%	07/17			25	25	-
29366AAA2	2.04% Series Senior Secured - Securitization Bond		2.04%	09/23			165	182	207
	Unamortized Premium and Discount – Net						(3)	(2)	(2)
	Other						4	4	4
TOTAL LONG-TERM DEBT(d)							3,220	2,826	2,252
Less Amount Due Within One Year							320	14	75
Long-Term Debt Excluding Amount Due Within One Year							$ 2,889	$ 2,812	$ 2,177
Fair Value of Long-Term Debt(a)							$ 3,149	$ 2,921	$ 2,211
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate							4.8%	4.9%	5.4%
(a) The fair value excludes lease obligations of $149 million at Entergy Louisiana and includes debt due within one year.  Fair values are classified as Level 2 in the fair value hierarchy (see pgs. 196 - 203 of
2013 10-K) and are based on prices derived from inputs such as benchmark yields and reported trades.
(b) Consists of pollution control revenue bonds and environmental revenue bonds.
(c) The bonds are secured by a series of collateral first mortgage bonds.
(d) The interest rate that applied to outstanding borrowings at the end of 2011 was 0.67%.
(e) The maturity date was extended to 03/19 in first quarter 2014.
Totals may not foot due to rounding.

						UNITS
						AUTHORIZED AND OUTSTANDING												CALL PRICE PER UNIT
PREFERRED MEMBERSHIP INTERESTS:						AS OF DECEMBER 31,						AS OF DECEMBER 31,						AS OF DECEMBER 31,
CUSIP			RATE			2013		2012		2011		2013		2012		2011		2013
		Without sinking fund:												(in millions)
		Cumulative, $100 liquidation value:
	293649307	6.95% Series(a)		6.95	%		1,000,000		1,000,000		1,000,000	$	100	$	100	$	100	$	100
		Total without sinking fund					1,000,000		1,000,000		1,000,000	$	100	$	100	$	100
(a) Series is callable at par.
Totals may not foot due to rounding.

UTILITY LONG-TERM DEBT AND PREFERRED STOCK
ENTERGY MISSISSIPPI, INC.
BONDS:				MATURITY	FIRST CALL	CURRENT OR	AS OF DECEMBER 31,
CUSIP		TYPE*	RATE	DATE	DATE	FIRST CALL PRICE	2013	2012	2011
								(in millions)
29364NAH1	5.15% Series	M	5.15%	02/13			$               -	$      100	$      100
29364NAQ1	3.25% Series	M	3.25%	06/16	Now	MW (T + .25%)	125	125	125
29364NAK4	4.95% Series(d)	M	4.95%	06/18	Now	100%	95	95	95
29364NAP3	6.64% Series	M	6.64%	07/19	Now	MW (T + .50%)	150	150	150
605277AF9	4.60% Series – Mississippi Business Finance Corp.	G(b,c)	4.6%	2022			-	16	16
453424BS1	4.90% Series – Independence County	G(b,c)	4.9%	2022	6/2/13	102%	30	30	30
29364N876	6.0% Series	M	6.0%	11/32	Now	100%	75	75	75
29364NAL2	6.25% Series	M	6.25%	04/34	Now	MW (T + .25%)	100	100	100
29364N843	6.20% Series	M	6.2%	04/40	4/15/15	100%	80	80	80
29364N835	6.00% Series	M	6.0%	05/51	5/1/16	100%	150	150	150
29364NAR9	3.10% Series	M	3.1%	07/23	Now	MW (T + .25 bps)	250	250	-
	Total bonds						1,055	1,171	921
OTHER LONG-TERM DEBT:
	Unamortized Premium and Discount – Net						(2)	(2)	(1)
TOTAL LONG-TERM DEBT(e)							1,054	1,170	920
Less Amount Due Within One Year							-	100	-
Long-Term Debt Excluding Amount Due Within One Year							$    1,054	$    1,070	$    920
Fair Value of Long-Term Debt(a)							$    1,067	$    1,231	$    986
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate							5.0%	5.0%	5.5%
(a) The fair value includes debt due within one year. Fair values are classified as Level 2 in the fair value hierarchy (see pgs. 196 - 203 of 2013 10-K) and are based on prices derived from inputs such as
benchmark yields and reported trades.
(b) Consists of pollution control revenue bonds and environmental revenue bonds.
(c) The bonds are secured by a series of collateral first mortgage bonds.
(d) The bonds were called in their entirety at par on 4/22/14.
Totals may not foot due to rounding.

			SHARES
			AUTHORIZED AND OUTSTANDING						CALL PRICE PER SHARE
PREFERRED STOCK:			AS OF DECEMBER 31,			AS OF DECEMBER 31,			AS OF DECEMBER 31,
CUSIP		RATE	2013	2012	2011	2013	2012	2011		2013
							(in millions)
	Without sinking fund:
	Cumulative, $100 par value:
29364N207	4.36% Series	4.36%	59,920	59,920	59,920	$        6	$        6	$        6		$103.88
29364N306	4.56% Series	4.56%	43,887	43,887	43,887	4	4	4		107.00
29364N405	4.92% Series	4.92%	100,000	100,000	100,000	10	10	10		102.88
	Cumulative, $25 par value:
29364N850	6.25% Series(a)	6.25%	1,200,000	1,200,000	1,200,000	30	30	30		$    25
	Total without sinking fund		$      1,403,807	1,403,807	1,403,807	$      50	$      50	$      50
(a) Series is callable at par.
Totals may not foot due to rounding.
ENTERGY NEW ORLEANS, INC.
BONDS:				MATURITY	FIRST CALL	CURRENT OR			AS OF DECEMBER 31,
CUSIP		TYPE*	RATE	DATE	DATE	FIRST CALL PRICE		2013	2012	2011
									(in millions)
29364PAH6	5.25% Series	M	5.25%	08/13				-	70	70
29364PAM5	5.10% Series	M	5.1%	12/20	Now	MW (T + .35%)		25	25	25
29364PAN3	3.9% Series	M	3.9%	07/23	Now	MW (T + .30%)		100	-	-
29364PAK9	5.6% Series	M	5.6%	09/24	Now	100%		33	33	33
29364PAJ2	5.65% Series	M	5.65%	09/29	Now	100%		38	38	38
29364P509	5.0% Series	M	5.0%	12/52	12/1/17	100%		30	30	-
	Total bonds							226	196	167
OTHER LONG-TERM DEBT:
	Unamortized Premium and Discount – Net							-	-	-
TOTAL LONG-TERM DEBT								226	196	167
Less Amount Due Within One Year								-	70	-
Long-Term Debt Excluding Amount Due Within One Year								$    226	$    126	$    167
Fair Value of Long-Term Debt(a)								$    218	$    201	$    169
*M = Mortgage; G = Governmental
Weighted-average annualized coupon rate								4.7%	5.3%	5.4%
(a) The fair value includes debt due within one year. Fair values are classified as Level 2 in the fair value hierarchy (see pgs. 196 - 203 of 2013 10-K) and are based on prices derived from inputs such as
benchmark yields and reported trades.
Totals may not foot due to rounding.

			SHARES
			AUTHORIZED AND OUTSTANDING						CALL PRICE PER SHARE
PREFERRED STOCK:			AS OF DECEMBER 31,			AS OF DECEMBER 31,			AS OF DECEMBER 31,
CUSIP		RATE	2013	2012	2011	2013	2012	2011		2013
	Without sinking fund:						(in millions)
	Cumulative, $100 par value:
29364P301	4.75% Series	4.75%	77,798	77,798	77,798	$        8	$        8	$        8		$105.00
29364P202	4.36% Series	4.36%	60,000	60,000	60,000	6	6	6		104.58
29364P400	5.56% Series	5.56%	60,000	60,000	60,000	6	6	6		102.59
	Total without sinking fund		197,798	197,798	197,798	20	$      20	$      20
Totals may not foot due to rounding.

UTILITY LONG-TERM DEBT AND PREFERRED STOCK
ENTERGY TEXAS, INC.
BONDS:				MATURITY	FIRST CALL	CURRENT OR		AS OF DECEMBER 31,
CUSIP		TYPE*	RATE	DATE	DATE	FIRST CALL PRICE	2013	2012	2011
								(in millions)
29365TAB0	3.60% Series	M	3.6%	06/15	Now	MW (T +. 25%)	$      200	$      200	$      200
29365TAA2	7.125% Series	M	7.125%	02/19	Now	MW (T + .50%)	500	500	500
29365TAC8	4.1% Series	M	4.1%	09/21	Now	MW (T + .35%)	75	75	75
29365T203	7.875% Series(b)	M	7.875%	06/39	06/14	100%	150	150	150
	Total bonds						925	925	925
OTHER LONG-TERM DEBT:
29365QAA8	5.51% Series Senior Secured, Series A - Securitization Bond		5.51%	10/13			-	-	18
29365QAB6	5.79% Series Senior Secured, Series A - Securitization Bond		5.79%	10/18			97	119	122
29365QAC4	5.93% Series Senior Secured, Series A - Securitization Bond		5.93%	06/22			114	114	114
29365KAA1	2.12% Series Senior Secured - Securitization Bond		2.12%	02/16			54	93	132
29365KAB9	3.65% Series Senior Secured - Securitization Bond		3.65%	08/19			145	145	145
29365KAC7	4.38% Series Senior Secured - Securitization Bond		4.38%	11/23			219	219	219
	Unamortized Premium and Discount – Net						(2)	(3)	(3)
	Other						5	5	5
TOTAL LONG-TERM DEBT							1,557	1,618	1,677
Less Amount Due Within One Year							-	-	-
Long-Term Debt Excluding Amount Due Within One Year							$ 1,557	$ 1,618	$ 1,677
Fair Value of Long-Term Debt(a)							$ 1,727	$ 1,886	$ 1,906
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate							5.5%	5.5%	5.4%
(a) The fair value includes debt due within one year. Fair values are classified as Level 2 in the fair value hierarchy (see pgs. 196 - 203 of 2013 10-K) and are based on prices derived from inputs such as
benchmark yields and reported trades.
(b) The bonds were called in their entirety at par on 6/16/14.
Totals may not foot due to rounding.
SYSTEM ENERGY RESOURCES, INC.
BONDS:				MATURITY	FIRST CALL	CURRENT OR		AS OF DECEMBER 31,
CUSIP		TYPE*	RATE	DATE	DATE	FIRST CALL PRICE	2013	2012	2011
								(in millions)
871911AR4	6.2% Series	M	6.2%	10/12			$               -	$               -	$      70
605277AB8	5.875% Series –  Mississippi Business Finance Corp.	G(b)	5.875%	2022	Now	100%	216	216	216
605277AC6	5.9% Series – Mississippi Business Finance Corp.	G(b)	5.9%	2022			-	-	103
179423AK4	6.2% Series – Claiborne County	G(b)	6.2%	2026			-	-	50
871911AS2	4.10% Series	M	4.1%	04/23	Now	MW (T + 0.40%)	250	250	-
	Total bonds						466	466	439
OTHER LONG-TERM DEBT:
361561AA1	Grand Gulf Lease Obligation 5.13%		5.13%				97	139	179
	6.29% Series F – Variable Interest Entity Note Payable		6.29%	09/13			-	70	70
	5.33% Series G – Variable Interest Entity Note Payable		5.33%	04/15			60	60	60
	4.02% Series H – Variable Interest Entity Note Payable		4.02%	02/17			50	50	-
	3.78% Series I – Variable Interest Entity Note Payable		3.78%	10/18			85	-	-
	Unamortized Premium and Discount – Net						(1)	(1)	(1)
	Other						-	-	-
TOTAL LONG-TERM DEBT							757	784	747
Less Amount Due Within One Year							49	112	110
Long-Term Debt Excluding Amount Due Within One Year							$    709	$    672	$    637
Fair Value of Long-Term Debt(a)							$    665	$    665	$    583
*M = Mortgage Bond; G = Governmental Bond
Weighted-average annualized coupon rate							4.8%	5.2%	5.8%
(a) The fair value excludes lease obligations of $97 million at System Energy and includes debt due within one year.  Fair values are classified as Level 2 in the fair value hierarchy (see pgs. 196 - 203 of
2013 10-K) and are based on prices derived from inputs such as benchmark yields and reported trades.
(b) Consists of pollution control revenue bonds and environmental revenue bonds.
Totals may not foot due to rounding.

UTILITY STATISTICAL INFORMATION
UTILITY TOTAL CAPABILITY
				OWNED &
	OPERATED			LEASED	OPERATED
As of December 31, 2013.	PLANTS	UNITS		(MW)(a)	(MW)
Plants that use fuel type:
Gas/Oil	24	55		14,247	14,585
Coal	3	5		2,255	3,867
Petroleum Coke	1	2		-	200
Total Fossil	28	62		16,502	18,652
Hydro	3	7		74	154
Nuclear	4	5		5,215	5,215
Total Capability	35	74		21,791	24,021
All plants that have units with multiple fuel types are in the Gas & Oil plant count.
(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions
based on the primary fuel (assuming no curtailments) that each station was designed to utilize.
UTILITY SELECTED OPERATING DATA
	2013	2012	2011	2010	2009
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil	30,364	31,011	30,042	26,637	21,767
Coal	13,567	13,320	14,915	15,616	15,101
Nuclear	38,676	37,714	40,102	42,339	41,851
Hydro	131	108	160	139	233
Total Net Generation	82,738	82,154	85,219	84,731	78,952
Purchased Power:
Affiliated Companies	349	713	803	738	741
Non-affiliated Companies	33,994	32,982	32,896	33,155	30,708
Total Purchased Power	34,343	33,695	33,699	33,893	31,449
Total Sources of Energy	117,081	115,850	118,918	118,625	110,401
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential	35,169	34,664	36,684	37,465	33,626
Commercial	28,547	28,724	28,720	28,831	27,476
Industrial	41,653	41,181	40,810	38,751	35,638
Governmental	2,412	2,435	2,474	2,463	2,408
Total Retail	107,781	107,004	108,688	107,510	99,148
Sales for Resale	3,020	3,200	4,111	4,372	4,862
Unbilled Energy	530	15	(131)	(173)	631
Total Electric Energy Sales	111,331	110,219	112,668	111,709	104,641
Line Losses and Company Usage	5,750	5,631	6,250	6,916	5,760
Total Uses of Energy	117,081	115,850	118,918	118,625	110,401
Peak Demand (MW)	21,581	21,866	22,387	21,799	21,009
Operational Summer Capacity at Peak (MW)	23,802	23,407	23,979	24,310	23,578
Annual System Load Factor (%)	62	60	60	62	60
Retail Electric Sales Growth Rate (%)	0.7	(1.5)	1.1	8.4	(1.5)
Retail Electric Sales Weather-Adjusted Growth Rate (%)	0.2	1.9	2.0	4.3	(1.5)
Regional Gross Domestic Product Rate (%)	2.4	1.5	1.9	7.0	(3.4)
National Gross Domestic Product Rate (%)	1.9	2.8	1.8	2.5	(2.8)
Average Fuel Cost (cents/KWh)
Natural Gas	4.12	3.15	4.85	5.39	5.64
Nuclear Fuel	0.92	0.85	0.81	0.78	0.66
Coal	2.70	2.60	2.31	2.00	2.04
Fuel Oil	-	-	-	-	-
Purchased Power	4.32	3.58	4.59	5.28	5.29
Totals may not foot due to rounding.

UTILITY STATISTICAL INFORMATION
2013 CONSOLIDATING UTILITY ELECTRIC STATISTICAL INFORMATION
	EAI	EGSL	ELL	EMI	ENOI	ETI	SERI	ELIMINATIONS	TOTAL	%
ELECTRIC OPERATING REVENUES ($ thousands)
Residential	772,059	465,292	838,636	526,618	197,197	596,396	-	-	3,396,198	38%
Commercial	469,367	417,154	585,833	432,240	182,748	327,299	-	-	2,414,641	27%
Industrial	432,852	502,057	954,956	155,742	34,916	324,767	-	-	2,405,290	27%
Governmental	19,206	21,334	45,900	41,967	66,553	23,535	-	-	218,495	2%
Total Retail	1,693,484	1,405,837	2,425,325	1,156,567	481,414	1,271,997	-	-	8,434,624	94%
Sales for Resale	429,141	420,642	117,231	116,514	27,301	416,285	735,065	(2,052,381)	209,798	2%
Other	67,534	55,416	84,379	61,459	16,326	40,517	24	(27,717)	297,938	3%
Total	2,190,159	1,881,895	2,626,935	1,334,540	525,041	1,728,799	735,089	(2,080,098)	8,942,360	100%
FUEL REVENUES (included in above revenues)
Residential	113,608	182,720	317,722	166,976	75,362	164,417	-	-	1,020,805	32%
Commercial	83,642	180,062	221,156	142,564	79,933	127,596	-	-	834,953	26%
Industrial	94,847	298,711	573,684	66,397	18,964	181,602	-	-	1,234,205	39%
Governmental	3,386	7,761	17,638	12,119	30,165	8,043	-	-	79,112	2%
Total Retail	295,483	669,254	1,130,200	388,056	204,424	481,658	-	-	3,169,075	100%
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil	3,200	2,991	9,882	7,240	1,500	5,551	-	-	30,364	26%
Coal	7,481	2,006	-	2,597	-	1,483	-	-	13,567	12%
Nuclear	11,946	7,587	9,368	-	-	-	9,775	-	38,676	33%
Hydro	131	-	-	-	-	-	-	-	131	0%
Total Net Generation	22,758	12,584	19,250	9,837	1,500	7,034	9,775	-	82,738	71%
Purchased Power:
Affiliated Companies	4,017	8,105	8,442	4,818	3,915	5,538	-	(34,486)	349	0%
Non-affiliated Companies	4,608	7,429	7,686	1,428	462	12,381	-	-	33,994	29%
Total Purchased Power	8,625	15,534	16,128	6,246	4,377	17,919	-	(34,486)	34,343	29%
Total Sources of Energy	31,383	28,118	35,378	16,083	5,877	24,953	9,775	(34,486)	117,081	100%
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential	7,921	5,206	8,820	5,629	1,867	5,726	-	-	35,169	33%
Commercial	5,929	5,208	6,194	4,815	1,998	4,402	-	-	28,547	26%
Industrial	6,769	9,021	16,713	2,265	481	6,404	-	-	41,653	39%
Governmental	241	228	495	409	758	282	-	-	2,412	2%
Total Retail	20,860	19,663	32,222	13,118	5,104	16,814	-	-	107,781	100%
Sales for Resale	8,929	7,467	1,936	1,847	508	6,999	9,794	(34,460)	3,020	-
Unbilled Energy	100	138	130	19	28	115	-	-	530	-
Total Electric Energy Sales	29,889	27,268	34,288	14,984	5,640	23,928	9,794	(34,460)	111,331	-
Line Losses and Company Usage	1,494	850	1,090	1,099	237	1,025	(19)	(26)	5,750	-
Total Uses of Energy	31,383	28,118	35,378	16,083	5,877	24,953	9,775	(34,486)	117,081	-
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential	9.75	8.94	9.51	9.36	10.56	10.42	-	-	9.66	-
Commercial	7.92	8.01	9.46	8.98	9.15	7.44	-	-	8.46	-
Industrial	6.39	5.57	5.71	6.88	7.26	5.07	-	-	5.77	-
Governmental	7.97	9.36	9.27	10.26	8.78	8.35	-	-	9.07	-
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31, 2013)
Residential	585,157	335,212	587,226	369,686	149,639	368,347	-	-	2,395,267	86%
Commercial	90,354	51,463	77,033	62,867	14,430	45,825	-	-	341,972	12%
Industrial	24,198	3,511	7,022	3,752	2,163	5,143	-	-	45,789	2%
Governmental	686	1,695	5,854	4,864	1,759	2,310	-	-	17,168	1%
Total Retail Customers	700,395	391,881	677,135	441,169	167,991	421,625	-	-	2,800,196	100%
Totals may not foot due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY ARKANSAS, INC.
	2013		2012		2011			2010			2009
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		772,059		765,564		755,807			773,012			768,500
Commercial		469,367		472,046		449,756			441,387			474,543
Industrial		432,852		439,467		421,384			414,791			433,321
Governmental		19,206		19,787		19,711			19,524			21,731
Total Retail		1,693,484		1,696,864		1,646,658			1,648,714			1,698,095
Sales for Resale		429,141		369,322		375,127			379,894			452,424
Other		67,534		60,818		62,525			53,839			60,743
Total Electric Operating Revenues		2,190,159		2,127,004		2,084,310			2,082,447			2,211,263
FUEL REVENUES (included in above revenues)
Residential		113,608		143,394		147,763			91,412			127,137
Commercial		83,642		109,845		110,070			65,809			95,959
Industrial		94,847		125,068		126,854			75,939			104,226
Governmental		3,386		4,651		4,965			2,976			4,416
Total Retail Fuel Revenues		295,483		382,958		389,652			236,136			331,738
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		3,200		1,889		1,078			984			1,003
Coal		7,481		7,179		7,636			8,233			7,955
Nuclear		11,946		15,493		14,194			15,023			15,168
Hydro		131		108		160			139			233
Total Net Generation		22,758		24,669		23,068			24,379			24,359
Purchased Power:
Affiliated Companies		4,017		2,940		4,280			3,887			3,776
Non-affiliated Companies		4,608		4,130		4,035			4,508			4,968
Total Purchased Power		8,625		7,070		8,315			8,395			8,744
Total Sources of Energy		31,383		31,739		31,383			32,774			33,103
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		7,921		7,859		8,229			8,501			7,464
Commercial		5,929		6,046		6,051			6,144			5,817
Industrial		6,769		6,925		7,029			7,082			6,376
Governmental		241		257		275			277			269
Total Retail		20,860		21,087		21,584			22,004			19,926
Sales for Resale		8,929		9,019		8,197			8,703			11,611
Unbilled Energy		100		13		(49	)		(123	)		111
Total Electric Energy Sales		29,889		30,119		29,732			30,584			31,648
Line Losses and Company Usage		1,494		1,620		1,651			2,190			1,455
Total Uses of Energy		31,383		31,739		31,383			32,774			33,103
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		9.75		9.74		9.18			9.09			10.30
Commercial		7.92		7.81		7.43			7.18			8.16
Industrial		6.39		6.35		5.99			5.86			6.80
Governmental		7.97		7.70		7.17			7.05			8.08
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		585,157		583,882		582,813			582,557			580,672
Commercial		90,354		89,618		88,895			88,725			87,929
Industrial		24,198		21,295		20,402			20,605			20,118
Governmental		686		681		693			674			661
Total Retail Customers		700,395		695,476		692,803			692,561			689,380
Totals may not foot due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY ARKANSAS, INC.
GENERATION PORTFOLIO
							PLANT						TOTAL PLANT – 2013
				OWNED &			AVG BTU								TOTAL
				LEASED			PER KWH	Emissions					NET	EXPENSES	PRODUCTION
			COMMERCIAL	CAPABILITY			NET	SO2	NOx	CO2	Hg(b)		GENERATION	PER NET	EXPENSE
PLANT	UNIT	OWNERSHIP	OPERATION	(MW)(a)	FUEL TYPE	PURPOSE	GENERATION(l)	(tons)	(tons)	(tons)	(lbs)	TECHNOLOGY(c)	(MWH)	MWH	($000)
Cecil Lynch(e)	2	100%	1949	-	Gas/Oil	Retired	-	-	-	-	-	-	(104)	(15,307.7)	1,592
	3	100%	1954	-	Gas/Oil	Retired		-	-	-	-	-
Harvey Couch(f)	1	100%	1943	-	Gas/Oil	Retired	-	-	-	-	-	-	(837)	(2,451.6)	2,052
	2	100%	1954	-	Gas/Oil	Retired		-	-	-	-	-
Lake Catherine(g)	1	100%	1950	-	Gas/Oil	Retired	12,514	-	-	-	-	-	477,685	81.0	38,697
	2	100%	1950	-	Gas/Oil	Retired		-	-	-	-	-
	3	100%	1953	-	Gas/Oil	Retired		-	49	12,041	-	-
	4	100%	1970	520	Gas/Oil	Peaking		2	806	338,218	-	-
Hamilton Moses(h)	1	100%	1951	-	Gas/Oil	Retired	-	-	-	-	-	-	-	-	-
	2	100%	1951	-	Gas/Oil	Retired		-	-	-	-	-
Mabelvale(i)	1	100%	1970	13	Gas/Oil	Peaking	76,050	-	-	-	-	-	78	7,666.7	598
	2	100%	1970	-	Gas/Oil	Retired		-	-	-	-	-
	3	100%	1970	13	Gas/Oil	Peaking		-	-	-	-	-
	4	100%	1970	-	Gas/Oil	Retired		-	-	-	-	-
Robert Ritchie(j)	1	100%	1961	-	Gas/Oil	Retired	-	-	-	-	-	-	(96)	(31.3)	3
	3	100%	1970	-	Gas/Oil	Retired		-	-	-	-	-	-	-	-
Ouachita	1	100%	2002	242	Gas	Intermediate	7,620	1	35	233,061	-	Dry LNB, SCR	1,000,706	40.3	40,302
	2	100%	2002	243	Gas	Intermediate		1	31	179,237	-	Dry LNB, SCR
Hot Spring	1	100%	2002	615	Gas	Intermediate	7,370	4	69	750,261	-	SCR	1,723,059	43.9	75,632
Independence	1	31.5%	1983	264	Coal	Base	10,137	3,963	1,492	1,510,644	77	OFA, ESP	1,461,737	33.3	48,724
White Bluff	1	57%	1980	465	Coal	Base	10,376	9,819	5,269	3,595,781	184	OFA, ESP	6,019,362	30.2	181,483
	2	57%	1981	468	Coal	Base		9,672	5,018	3,544,437	182	OFA, ESP
Cecil Lynch(k)	Diesel	100%	1967	-	Oil	Retired	-	-	-	-	-		-	-	(34)
Carpenter	1	100%	1932	31	Hydro	Peaking	-	-	-	-	-	-	101,163	9.0	911
	2	100%	1932	31	Hydro	Peaking		-	-	-	-	-
Remmel	1	100%	1925	4	Hydro	Peaking	-	-	-	-	-	-	29,446	28.0	823
	2	100%	1925	4	Hydro	Peaking		-	-	-	-	-
	3	100%	1925	4	Hydro	Peaking		-	-	-	-	-
Arkansas
Nuclear One	1	100%	1974	834	Nuclear PWR(d)	Base	10,337	-	-	-	-	-	11,946,220	22.9	273,003
	2	100%	1980	985	Nuclear PWR(d)	Base		-	-	-	-	-
Total				4,736									22,758,419	29.2	663,786
(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel
(assuming no curtailments) that each station was designed to utilize.
(b) Mercury emissions calculated using 2013 unit heat input and 5.37 x 10-6 lb hg/MMBtu emission rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.
(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP),
Low NOx Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA),
Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection.  Currently have no SO2, CO2 or Mercury Control equipment operating on any unit.
(d) PWR = Pressurized Water Reactor.
(e) Cecil Lynch Units 2 and 3 were officially retired on Jun. 21, 2013 and Dec. 19, 2013.
(f) Harvey Couch Unit 2 was officially retired on Dec. 19, 2013.
(g) Lake Catherine Units 1, 2 and 3 were officially retired on Dec. 19, 2013.
(h) Hamilton Moses Units 1 and 2 were officially retired on Feb. 6, 2013.
(i) Mabelvale Units 2 and 4 were officially retired on Dec. 19, 2013.
(j) Robert Ritchie Units 1 and 3 were officially retired on Feb. 6, 2013 and Jun. 21, 2013.
(k) Cecil Lynch Diesel Unit was officially retired on May 1, 2013.
(l) The nuclear heat rate as reflected in the FERC Form 1 is calculated by obtaining the thermal generation in MWhs from the plant multiplied by the industry standard of 3.4126 to obtain the MMBtu equivalency
Calculations may differ due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY GULF STATES LOUISIANA, L.L.C.
	2013		2012		2011			2010			2009
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		465,292		388,725		479,060			498,319			393,490
Commercial		417,154		349,210		416,321			426,342			354,038
Industrial		502,057		391,776		490,378			488,974			383,272
Governmental		21,334		18,522		20,925			20,350			17,625
Total Retail		1,405,837		1,148,233		1,406,684			1,433,985			1,148,425
Sales for Resale		420,642		410,622		614,429			541,219			579,358
Other		55,416		47,310		48,435			40,506			48,827
Total Electric Operating Revenues		1,881,895		1,606,165		2,069,548			2,015,710			1,776,610
FUEL REVENUES (included in above revenues)
Residential		182,720		134,464		186,547			193,863			177,483
Commercial		180,062		135,686		178,013			182,546			175,960
Industrial		298,711		219,667		292,036			292,789			251,212
Governmental		7,761		5,850		7,453			7,251			7,341
Total Retail Fuel Revenues		669,254		495,667		664,049			676,449			611,996
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		2,991		3,773		3,547			2,533			1,705
Coal		2,006		2,033		2,605			2,535			2,472
Nuclear		7,587		7,805		7,686			8,363			7,836
Hydro		-		-		-			-			-
Total Net Generation		12,584		13,611		13,838			13,431			12,013
Purchased Power:
Affiliated Companies		8,105		7,357		6,446			7,021			6,768
Non-affiliated Companies		7,429		7,936		10,007			10,437			9,720
Total Purchased Power		15,534		15,293		16,453			17,458			16,488
Total Sources of Energy		28,118		28,904		30,291			30,889			28,501
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		5,206		5,176		5,383			5,538			5,090
Commercial		5,208		5,287		5,239			5,274			5,058
Industrial		9,021		8,890		9,041			8,801			7,601
Governmental		228		228		222			210			213
Total Retail		19,663		19,581		19,885			19,823			17,962
Sales for Resale		7,467		8,668		9,608			10,221			9,630
Unbilled Energy		138		11		(39	)		(51	)		149
Total Electric Energy Sales		27,268		28,260		29,454			29,993			27,741
Line Losses and Company Usage		850		644		837			896			760
Total Uses of Energy		28,118		28,904		30,291			30,889			28,501
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		8.94		7.51		8.90			9.00			7.73
Commercial		8.01		6.61		7.95			8.08			7.00
Industrial		5.57		4.41		5.42			5.56			5.04
Governmental		9.36		8.12		9.43			9.69			8.27
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		335,212		331,735		328,718			326,497			324,285
Commercial		51,463		50,616		50,277			49,886			49,319
Industrial		3,511		3,379		3,278			3,265			3,436
Governmental		1,695		1,698		1,615			1,627			1,652
Total Retail Customers		391,881		387,428		383,888			381,275			378,692
Totals may not foot due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY GULF STATES LOUISIANA, L.L.C.
GENERATION PORTFOLIO
							PLANT						TOTAL PLANT – 2013
				OWNED &			AVG BTU								TOTAL
				LEASED			PER KWH	Emissions					NET	EXPENSES	PRODUCTION
			COMMERCIAL	CAPABILITY			NET	SO2	NOx	CO2	Hg(b)		GENERATION	PER NET	EXPENSE
PLANT	UNIT	OWNERSHIP	OPERATION	(MW)(a)	FUEL TYPE	PURPOSE	GENERATION(g)	(tons)	(tons)	(tons)	(lbs)	TECHNOLOGY(c)	(MWH)	MWH	($000)
LA Station 2 (d)	10	100%	1950	-	Gas	Reserve	-	-	-	-	-	-	-	-	387
	11	100%	1950	-	Gas	Reserve		-	-	-	-	-
	12	100%	1953	-	Gas	Reserve		-	-	-	-	-
Willow Glen	1	100%	1960	-	Gas/Oil	Reserve	12,060	-	41	38,351	-	-	740,200	59.9	44,327
	2	100%	1964	181	Gas/Oil	Peaking		-	92	73,642	-	-
	3	100%	1968	-	Gas	Reserve		-	-	-	-	ESP
	4	100%	1973	481	Gas/Oil	Peaking		2	584	302,000	-	-
	5	100%	1976	-	Gas/Oil	Reserve		-	-	-	-	-
Roy S. Nelson	3	100%	1960	-	Gas/Oil	Reserve	12,580	-	98	82,754	-	-	1,502,556	53.2	79,979
	4	100%	1970	424	Gas/Oil	Intermediate		5	1,173	1,000,253	-	-
Calcasieu	1	100%	2000	143	Gas	Peaking	11,500	1	98	105,860	-	Dry LNB	360,912	62.8	22,662
	2	100%	2001	159	Gas	Peaking		1	91	129,880	-	Dry LNB
Ouachita	3	100%	2002	246	Gas	Intermediate	7,535	1	26	157,890	-	Dry LNB, SCR	387,820	42.0	16,289
Roy S. Nelson	6	40%	1982	222	Coal	Base	11,410	4,611	1,126	1,475,892	73	LNB w/ Sep OFA, ESP	1,201,012	40.7	48,854
Big Cajun 2	3	24%	1983	145	Coal	Base	10,350	2,883	726	960,378	49	LNB w/ OFA, ESP	804,766	32.2	25,913
River Bend	1	100%(e)	1986	968	Nuclear BWR(f)	Base	10,850	-	-	-	-	-	7,587,441	27.3	206,903
Total				2,969									12,584,707	35.4	445,314
(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel
(assuming no curtailments) that each station was designed to utilize.
(b) Mercury emissions calculated using 2013 unit heat input and 5.37 x 10-6 lb hg/MMBtu emission rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.
(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP),
Low NOx Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA),
Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection.  Currently have no SO2, CO2 or Mercury Control equipment operating on any unit.
(d) EGSL also owns and operates LA Station 1 units 1a, 2a, 3a and 4a; these units are under a long-term contract with an external 3rd party, which owns all of the output of these units.
(e) 30% of River Bend is not subject to rate regulation by the Public Utility Commission of Texas, the Louisiana Public Service Commission, nor various municipal authorities.
(f) BWR = Boiling Water Reactor.
(g) The nuclear heat rate as reflected in the FERC Form 1 is calculated by obtaining the thermal generation in MWhs from the plant multiplied by the industry standard of 3.4126 to obtain the MMBtu equivalency
Calculations may differ due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY LOUISIANA, LLC
	2013		2012		2011		2010		2009
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		838,636		687,043		829,663		840,011		669,084
Commercial		585,833		482,382		549,142		543,308		456,274
Industrial		954,956		731,215		867,491		817,454		664,377
Governmental		45,900		37,940		41,900		42,124		35,760
Total Retail		2,425,325		1,938,580		2,288,196		2,242,897		1,825,495
Sales for Resale		117,231		138,675		145,009		225,011		256,596
Other		84,379		72,188		75,710		70,858		101,495
Total Electric Operating Revenues		2,626,935		2,149,443		2,508,915		2,538,766		2,183,586
FUEL REVENUES (included in above revenues)
Residential		317,722		215,717		332,827		360,847		287,909
Commercial		221,156		151,733		218,649		231,104		194,759
Industrial		573,684		393,942		535,592		523,895		435,112
Governmental		17,638		11,925		16,595		18,067		15,388
Total Retail Fuel Revenues		1,130,200		773,317		1,103,663		1,133,913		933,168
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		9,882		11,530		10,506		9,429		7,090
Coal		-		-		-		-		-
Nuclear		9,368		7,854		8,929		10,276		8,949
Hydro		-		-		-		-		-
Total Net Generation		19,250		19,384		19,435		19,705		16,039
Purchased Power:
Affiliated Companies		8,442		8,163		7,484		5,783		7,818
Non-affiliated Companies		7,686		7,653		8,682		9,614		7,644
Total Purchased Power		16,128		15,816		16,166		15,397		15,462
Total Sources of Energy		35,378		35,200		35,601		35,102		31,501
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		8,820		8,703		9,303		9,533		8,684
Commercial		6,194		6,112		6,155		6,164		5,867
Industrial		16,713		16,416		15,813		14,473		13,386
Governmental		495		479		473		479		459
Total Retail		32,222		31,710		31,744		30,649		28,396
Sales for Resale		1,936		2,222		2,330		2,961		1,621
Unbilled Energy		130		32		38		27		164
Total Electric Energy Sales		34,288		33,964		34,112		33,637		30,181
Line Losses and Company Usage		1,090		1,236		1,489		1,465		1,320
Total Uses of Energy		35,378		35,200		35,601		35,102		31,501
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		9.51		7.89		8.92		8.81		7.70
Commercial		9.46		7.89		8.92		8.81		7.78
Industrial		5.71		4.45		5.49		5.65		4.96
Governmental		9.27		7.92		8.86		8.79		7.79
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		587,226		583,975		580,627		578,466		575,388
Commercial		77,033		76,509		76,130		75,493		74,608
Industrial		7,022		6,914		6,908		6,971		7,247
Governmental		5,854		5,804		5,767		5,704		5,539
Total Retail Customers		677,135		673,202		669,432		666,634		662,782
Totals may not foot due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY LOUISIANA, LLC
GENERATION PORTFOLIO
							PLANT						TOTAL PLANT – 2013
				OWNED &			AVG BTU								TOTAL
				LEASED			PER KWH	Emissions					NET	EXPENSES	PRODUCTION
			COMMERCIAL	CAPABILITY			NET	SO2	NOx	CO2	Hg(b)		GENERATION	PER NET	EXPENSE
PLANT	UNIT	OWNERSHIP	OPERATION	(MW)(a)	FUEL TYPE	PURPOSE	GENERATION(e)	(tons)	(tons)	(tons)	(lbs)	TECHNOLOGY(c)	(MWH)	MWH	($000)
Acadia	2	100%	2002	546	Gas	Intermediate	7,590	3	60	678,116	-	SCR	1,529,941	38.5	58,925
Buras	8	100%	1971	12	Gas/Oil	Peaking	37,180	-	-	-	-	-	64	5,718.8	366
Little Gypsy	1	100%	1961	238	Gas/Oil	Intermediate	13,030	1	226	154,868	-	-	1,456,085	62.3	90,638
	2	100%	1966	411	Gas/Oil	Intermediate		2	233	385,886	-	-
	3	100%	1969	520	Gas/Oil	Intermediate		3	1,570	552,220	-	-
Monroe	10	100%	1961	-	Gas	Retired	-	-	-	-	-	-	-	-	(29)
	11	100%	1965	-	Gas	Retired		-	-	-	-	-
	12	100%	1968	-	Gas	Retired		-	-	-	-	-
Ninemile Point	1	100%	1951	-	Gas/Oil	Retired	11,000	-	3	2,333	-	-	4,283,882	48.0	205,690
	2	100%	1953	-	Gas/Oil	Retired		-	-	-	-	-
	3	100%	1955	103	Gas/Oil	Intermediate		1	156	123,930	-	-
	4	100%	1971	699	Gas/Oil	Intermediate		7	1,666	1,296,707	-	-
	5	100%	1973	717	Gas/Oil	Intermediate		7	2,129	1,432,163	-	-
Perryville	1	100%	2002	530	Gas	Intermediate	7,410	4	96	741,817	-	Dry LNB, SCR	1,636,598	42.9	70,209
	2	100%	2001	146	Gas	Peaking		-	3	9,602	-	Dry LNB
Sterlington	6	100%	1958	-	Gas/Oil	Retired	18,150	-	-	-	-	-	10,820	305.9	3,310
	7	100%	1974	126	Gas/Oil	Peaking		-	34	10,196	-	-
Waterford	1	100%	1975	411	Gas/Oil	Intermediate	14,790	17	285	368,482	-	-	964,527	69.5	67,059
	2	100%	1975	411	Gas/Oil	Intermediate		2	265	360,750	-	-
	4	100%	2009	33	Oil	Peaking	-	-	4	1,259	-	Steam Injection	-	-	-
Waterford	3	100%	1985	1,156	Nuclear PWR(d)	Base	10,934	-	-	-	-	-	9,367,757	25.1	235,361
Total				6,059									19,249,674	38.0	731,529
(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel
(assuming no curtailments) that each station was designed to utilize.
(b) Mercury emissions calculated using 2013 unit heat input and 5.37 x 10-6 lb hg/MMBtu emission rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.
(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP),
Low NOx Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA),
Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection.  Currently have no SO2, CO2 or Mercury Control equipment operating on any unit.
(d) PWR = Pressurized Water Reactor.
(e) The nuclear heat rate as reflected in the FERC Form 1 is calculated by obtaining the thermal generation in MWhs from the plant multiplied by the industry standard of 3.4126 to obtain the MMBtu equivalency
Calculations may differ due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY MISSISSIPPI, INC.
	2013		2012		2011			2010			2009
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		526,618		453,707		490,088			508,571			466,632
Commercial		432,240		381,346		401,276			405,577			395,444
Industrial		155,742		140,460		145,792			144,581			146,608
Governmental		41,967		36,289		37,302			37,754			37,740
Total Retail		1,156,567		1,011,802		1,074,458			1,096,483			1,046,424
Sales for Resale		116,514		46,962		131,334			87,670			79,408
Other		61,459		61,601		60,678			48,769			54,275
Total Electric Operating Revenues		1,334,540		1,120,366		1,266,470			1,232,922			1,180,107
FUEL REVENUES (included in above revenues)
Residential		166,976		137,760		181,581			177,354			179,338
Commercial		142,564		122,805		154,748			145,950			158,937
Industrial		66,397		58,721		69,808			63,696			70,679
Governmental		12,119		10,210		12,861			12,031			13,614
Total Retail Fuel Revenues		388,056		329,496		418,998			399,031			422,568
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		7,240		6,305		5,978			5,469			3,583
Coal		2,597		2,605		2,749			2,974			2,847
Nuclear		-		-		-			-			-
Hydro		-		-		-			-			-
Total Net Generation		9,837		8,910		8,727			8,443			6,430
Purchased Power:
Affiliated Companies		4,818		4,415		5,080			5,467			6,127
Non-affiliated Companies		1,428		1,393		1,524			1,607			1,752
Total Purchased Power		6,246		5,808		6,604			7,074			7,879
Total Sources of Energy		16,083		14,718		15,331			15,517			14,309
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		5,629		5,550		5,848			6,077			5,358
Commercial		4,815		4,915		4,985			5,000			4,756
Industrial		2,265		2,400		2,326			2,250			2,178
Governmental		409		408		415			416			405
Total Retail		13,118		13,273		13,574			13,743			12,697
Sales for Resale		1,847		497		763			670			528
Unbilled Energy		19		24		(69	)		(18	)		74
Total Electric Energy Sales		14,984		13,794		14,268			14,395			13,299
Line Losses and Company Usage		1,099		924		1,063			1,122			1,010
Total Uses of Energy		16,083		14,718		15,331			15,517			14,309
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		9.36		8.17		8.38			8.37			8.71
Commercial		8.98		7.76		8.05			8.11			8.31
Industrial		6.88		5.85		6.27			6.43			6.73
Governmental		10.26		8.91		8.99			9.08			9.32
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		369,686		368,660		366,697			366,722			365,804
Commercial		62,867		63,083		62,762			62,858			62,613
Industrial		3,752		3,598		3,488			3,450			2,749
Governmental		4,864		4,419		4,358			4,322			4,259
Total Retail Customers		441,169		439,760		437,305			437,352			435,425
Totals may not foot due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY MISSISSIPPI, INC.
GENERATION PORTFOLIO
							PLANT						TOTAL PLANT – 2013
				OWNED &			AVG BTU								TOTAL
				LEASED			PER KWH	Emissions					NET	EXPENSES	PRODUCTION
			COMMERCIAL	CAPABILITY			NET	SO2	NOx	CO2	Hg(b)		GENERATION	PER NET	EXPENSE
PLANT	UNIT	OWNERSHIP	OPERATION	(MW)(a)	FUEL TYPE	PURPOSE	GENERATION(d)	(tons)	(tons)	(tons)	(lbs)	TECHNOLOGY(c)	(MWH)	MWH	($000)
Attala	1	100%	2001	460	Gas	Intermediate	7,280	4	71	798,747	-	Dry LNB, SCR	2,193,525	35.6	78,011
Hinds	1	100%	2001	463	Gas	Intermediate	7,270	4	55	720,987	-	SCR	1,850,561	37.4	69,254
Baxter Wilson	1	100%	1967	495	Gas/Oil	Intermediate	12,180	2	635	334,842	-	-	1,812,970	62.0	112,388
	2	100%	1971	667	Gas/Oil	Intermediate		6	2,714	870,167	-	Combus Mod/Fuel Reburn
Delta	1	100%	1953	-	Gas/Oil	Retired	-	-	-	-	-	-	(103)	(1,339.8)	138
	2	100%	1953	-	Gas/Oil	Retired		-	-	-	-	-
Gerald Andrus	1	100%	1975	673	Gas/Oil	Intermediate	11,750	5	1,315	899,637	-	OFA	1,305,735	52.6	68,638
Natchez	1	100%	1951	-	Gas/Oil	Retired	-	-	-	-	-	-	-	-	-
Rex Brown	1	100%	1948	-	Gas	Retired	18,400	-	-	-	-	-	77,637	142.3	11,047
	3	100%	1951	40	Gas/Oil	Peaking		-	12	3,888	-	-
	4	100%	1959	193	Gas/Oil	Intermediate		1	258	102,074	-	-
	5	100%	1968	9	Oil	Peaking		-	-	-	-	-
Independence	1	25%	1983	209	Coal	Base	10,284	3,145	1,184	1,198,924	61	OFA, ESP	2,597,385	32.6	84,717
	2	25%	1984	210	Coal	Base		4,068	1,494	1,540,146	79	OFA, ESP
Total				3,420									9,837,710	43.1	424,193
(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel
(assuming no curtailments) that each station was designed to utilize.
(b) Mercury emissions calculated using 2013 unit heat input and 5.37 x 10-6 lb hg/MMBtu emission rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.
(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP),
Low NOx Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA),
Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection.  Currently have no SO2, CO2 or Mercury Control equipment operating on any unit.
(d) The nuclear heat rate as reflected in the FERC Form 1 is calculated by obtaining the thermal generation in MWhs from the plant multiplied by the industry standard of 3.4126 to obtain the MMBtu equivalency
Calculations may differ due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY NEW ORLEANS, INC.
	2013		2012			2011			2010			2009
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		197,197		174,108			175,994			196,391			167,794
Commercial		182,748		163,911			153,824			173,536			166,454
Industrial		34,916		31,374			29,800			35,826			37,225
Governmental		66,553		62,718			59,840			70,146			69,306
Total Retail		481,414		432,112			419,458			475,899			440,779
Sales for Resale		27,301		43,967			95,704			56,500			88,010
Other		16,326		11,554			14,066			10,703			7,196
Total Electric Operating Revenues		525,041		487,633			529,228			543,102			535,985
FUEL REVENUES (included in above revenues)
Residential		75,362		56,274			59,406			65,146			62,017
Commercial		79,933		61,972			60,829			66,088			72,121
Industrial		18,964		15,354			15,310			17,253			19,103
Governmental		30,165		24,768			24,790			28,073			31,866
Total Retail Fuel Revenues		204,424		158,368			160,335			176,560			185,107
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		1,500		2,344			2,412			1,867			2,202
Coal		-		-			-			-			-
Nuclear		-		-			-			-			-
Hydro		-		-			-			-			-
Total Net Generation		1,500		2,344			2,412			1,867			2,202
Purchased Power:
Affiliated Companies		3,915		3,385			3,650			3,839			3,760
Non-affiliated Companies		462		448			489			511			590
Total Purchased Power		4,377		3,833			4,139			4,350			4,350
Total Sources of Energy		5,877		6,177			6,551			6,217			6,552
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		1,867		1,772			1,888			1,858			1,577
Commercial		1,998		1,968			1,939			1,899			1,813
Industrial		481		484			498			503			526
Governmental		758		785			795			809			805
Total Retail		5,104		5,009			5,120			5,069			4,721
Sales for Resale		508		986			1,186			919			1,543
Unbilled Energy		28		(2	)		(1	)		(18	)		29
Total Electric Energy Sales		5,640		5,993			6,305			5,970			6,293
Line Losses and Company Usage		237		184			246			247			259
Total Uses of Energy		5,877		6,177			6,551			6,217			6,552
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		10.56		9.82			9.32			10.57			10.64
Commercial		9.15		8.33			7.93			9.14			9.18
Industrial		7.26		6.48			5.98			7.12			7.08
Governmental		8.78		7.99			7.53			8.67			8.61
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		149,639		146,706			142,680			138,659			132,602
Commercial		14,430		14,155			13,920			14,079			13,064
Industrial		2,163		2,112			2,288			2,277			2,311
Governmental		1,759		1,769			1,738			2,079			1,747
Total Retail Customers		167,991		164,742			160,626			157,094			149,724
Totals may not foot due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY NEW ORLEANS, INC.
GENERATION PORTFOLIO
							PLANT						TOTAL PLANT – 2013
				OWNED &			AVG BTU								TOTAL
				LEASED			PER KWH	Emissions					NET	EXPENSES	PRODUCTION
			COMMERCIAL	CAPABILITY			NET	SO2	NOx	CO2	Hg(b)		GENERATION	PER NET	EXPENSE
PLANT	UNIT	OWNERSHIP	OPERATION	(MW)(a)	FUEL TYPE	PURPOSE	GENERATION(d)	(tons)	(tons)	(tons)	(lbs)	TECHNOLOGY(c)	(MWH)	MWH	($000)
A. B. Paterson	3	100%	1950	-	Gas/Oil	Retired	-	-	-	-	-	-	-	-	-
	4	100%	1954	-	Gas/Oil	Retired		-	-	-	-	-
Michoud	1	100%	1957	-	Gas/Oil	Retired	11,272	-	-	-	-	-	1,499,897	62.0	93,026
	2	100%	1963	239	Gas/Oil	Intermediate		2	539	357,721	-	-
	3	100%	1967	542	Gas/Oil	Intermediate		3	616	631,615	-	Combus Mod/Fuel Reburn
A. B. Paterson	5	100%	1967	-	Oil	Retired	-	-	-	-	-	-	-	-	-
Total				781									1,499,897	62.0	93,026
(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel
(assuming no curtailments) that each station was designed to utilize.
(b) Mercury emissions calculated using 2013 unit heat input and 5.37 x 10-6 lb hg/MMBtu emission rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.
(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP),
Low NOx Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA),
Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection.  Currently have no SO2, CO2 or Mercury Control equipment operating on any unit.
(d) The nuclear heat rate as reflected in the FERC Form 1 is calculated by obtaining the thermal generation in MWhs from the plant multiplied by the industry standard of 3.4126 to obtain the MMBtu equivalency
Calculations may differ due to rounding.

SYSTEM ENERGY RESOURCES, INC.
	2013			2012			2011		2010			2009
ELECTRIC OPERATING REVENUES ($ thousands)		735,089			622,118			563,411		558,584			554,007
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		-			-			-		-			-
Coal		-			-			-		-			-
Nuclear		9,775			6,562			9,293		8,677			9,898
Hydro		-			-			-		-			-
Total Net Generation		9,775			6,562			9,293		8,677			9,898
Purchased Power		-			-			-		-			-
Total Sources of Energy		9,775			6,562			9,293		8,677			9,898
USES OF ENERGY (GWh)
Electric Energy Sales		9,794			6,602			9,293		8,692			9,898
Unbilled Energy		-			-			-		-			-
Line Losses and Company Usage		(19	)		(40	)		-		(15	)		-
Total Uses of Energy		9,775			6,562			9,293		8,677			9,898
Totals may not foot due to rounding.

SYSTEM ENERGY RESOURCES, INC.

GENERATION PORTFOLIO

PLANT

TOTAL PLANT – 2013

OWNED &

AVG BTU

TOTAL

LEASED

PER KWH

Emissions

NET

EXPENSES

PRODUCTION

COMMERCIAL

CAPABILITY

NET

SO2

NOx

CO2

Hg

GENERATION

PER NET

EXPENSE

PLANT

UNIT

OWNERSHIP

OPERATION

(MW)(a)

FUEL TYPE

PURPOSE

GENERATION(c)

(tons)

(tons)

(tons)

(lbs)

TECHNOLOGY

(MWH)

MWH

($000)

Grand Gulf

1

90%

1985

1,272

Nuclear BWR(b)

Base

10,503

-

-

-

-

-

9,793,557

25.8

253,974

Total

1,272

9,793,557

25.8

253,974

(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments)

that each station was designed to utilize. Reflects estimate of the rerate for recovered performance (~ 55 MW) and uprate (~ 178 MW) completed in 2012. Approved Summer 2013 rating is 1,277 MW.

(b) BWR = Boiling Water Reactor.

(c) The nuclear heat rate as reflected in the FERC Form 1 is calculated by obtaining the thermal generation in MWhs from the plant multiplied by the industry standard of 3.4126 to obtain the MMBtu equivalency

Calculations may differ due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY TEXAS, INC.
	2013		2012			2011			2010		2009
ELECTRIC OPERATING REVENUES ($ thousands)
Residential		596,396		553,107			638,161			558,733		533,146
Commercial		327,299		325,342			368,614			320,935		336,876
Industrial		324,767		299,441			351,731			305,455		332,303
Governmental		23,535		22,940			25,955			22,527		22,797
Total Retail		1,271,997		1,200,830			1,384,461			1,207,650		1,225,122
Sales for Resale		416,285		348,783			336,555			449,233		303,682
Other		40,517		31,883			36,183			33,548		35,019
Total Electric Operating Revenues		1,728,799		1,581,496			1,757,199			1,690,431		1,563,823
FUEL REVENUES (included in above revenues)
Residential		164,417		164,387			231,058			228,693		250,230
Commercial		127,596		128,204			166,223			164,098		186,662
Industrial		181,602		165,768			214,474			210,357		229,164
Governmental		8,043		8,070			10,836			10,333		11,479
Total Retail Fuel Revenues		481,658		466,429			622,591			613,481		677,535
SOURCES OF ENERGY (GWh)
Net Generation:
Gas & Oil		5,551		5,170			6,521			6,355		6,184
Coal		1,483		1,503			1,925			1,874		1,827
Nuclear		-		-			-			-		-
Hydro		-		-			-			-		-
Total Net Generation		7,034		6,673			8,446			8,229		8,011
Purchased Power:
Affiliated Companies		5,538		5,754			6,546			7,537		6,349
Non-affiliated Companies		12,381		11,423			8,159			6,478		6,034
Total Purchased Power		17,919		17,177			14,705			14,016		12,383
Total Sources of Energy		24,953		23,850			23,151			22,245		20,394
USES OF ENERGY (GWh)
Electric Energy Sales:
Residential		5,726		5,604			6,034			5,958		5,453
Commercial		4,402		4,396			4,433			4,271		4,165
Industrial		6,404		6,066			6,102			5,642		5,570
Governmental		282		278			294			271		258
Total Retail		16,814		16,344			16,863			16,142		15,446
Sales for Resale		6,999		6,530			5,416			5,058		3,861
Unbilled Energy		115		(64	)		(11	)		10		104
Total Electric Energy Sales		23,928		22,810			22,268			21,210		19,411
Line Losses and Company Usage		1,025		1,040			883			1,035		983
Total Uses of Energy		24,953		23,850			23,151			22,245		20,394
AVERAGE ELECTRIC REVENUE (cents/KWh)
Residential		10.42		9.87			10.58			9.38		9.78
Commercial		7.44		7.40			8.32			7.51		8.09
Industrial		5.07		4.94			5.76			5.41		5.97
Governmental		8.35		8.25			8.83			8.31		8.84
NUMBER OF RETAIL ELECTRIC CUSTOMERS
(as of December 31)
Residential		368,347		364,997			360,909			356,999		352,682
Commercial		45,825		45,247			44,760			44,080		43,375
Industrial		5,143		4,932			4,809			4,815		4,896
Governmental		2,310		2,271			2,248			2,213		2,159
Total Retail Customers		421,625		417,447			412,726			408,107		403,112
Totals may not foot due to rounding.

UTILITY STATISTICAL INFORMATION
ENTERGY TEXAS, INC.
GENERATION PORTFOLIO
							PLANT						TOTAL PLANT – 2013
				OWNED &			AVG BTU								TOTAL
				LEASED			PER KWH	Emissions					NET	EXPENSES	PRODUCTION
			COMMERCIAL	CAPABILITY			NET	SO2	NOx	CO2	Hg(b)		GENERATION	PER NET	EXPENSE
PLANT	UNIT	OWNERSHIP	OPERATION	(MW)(a)	FUEL TYPE	PURPOSE	GENERATION(d)	(tons)	(tons)	(tons)	(lbs)	TECHNOLOGY(c)	(MWH)	MWH	($000)
Roy S. Nelson	6	30%	1982	163	Coal	Base	11,410	3,408	832	1,090,876	54	LNB w/ Sep OFA, ESP	887,702	41.3	36,650
Big Cajun 2	3	18%	1983	108	Coal	Base	10,350	2,131	537	709,845	36	LNB w/ OFA, ESP	594,827	32.1	19,140
Lewis Creek	1	100%	1970	230	Gas/Oil	Intermediate	11,600	3	99	609,455	-	SCR	1,454,982	55.5	80,700
	2	100%	1971	230	Gas/Oil	Intermediate		2	91	405,077	-	SCR
Sabine	1	100%	1962	212	Gas/Oil	Intermediate	11,470	2	520	368,504	-	-	4,096,269	50.1	205,010
	2	100%	1962	212	Gas/Oil	Intermediate		2	311	365,962	-	-
	3	100%	1966	396	Gas/Oil	Intermediate		3	543	595,308	-	LNB w/ Sep OFA
	4	100%	1974	533	Gas	Intermediate		5	1,037	1,036,520	-	Combus Mod/Fuel Reburn
	5	100%	1979	470	Gas/Oil	Intermediate		2	278	401,380	-	LNB w/ Closed-coupled OFA
Total				2,554									7,033,780	48.6	341,500
(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel
(assuming no curtailments) that each station was designed to utilize.
(b) Mercury emissions calculated using 2013 unit heat input and 5.37 x 10-6 lb hg/MMBtu emission rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.
(c) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP),
Low NOx Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA),
Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection.  Currently have no SO2, CO2 or Mercury Control equipment operating on any unit.
(d) The nuclear heat rate as reflected in the FERC Form 1 is calculated by obtaining the thermal generation in MWhs from the plant multiplied by the industry standard of 3.4126 to obtain the MMBtu equivalency
Calculations may differ due to rounding.

UTILITY STATISTICAL INFORMATION
UTILITY NUCLEAR PLANT STATISTICS
The following table shows plant performance for 2009 – 2013 based on 18/24 month operating cycle.
CAPABILITY FACTOR (%)	2013	2012	2011	2010	2009
ANO	79.5	93.7	92.1	92.3	90.9
Grand Gulf	74.6	77.3	90.7	92.4	92.1
River Bend	90.0	90.3	93.4	92.7	94.2
Waterford 3	80.7	85.6	91.4	91.4	91.4
Entergy Southeast Average	80.8	88.1	91.9	92.2	91.9
Industry Average	89.1	86.8	89.3	89.3	90.2
The following table shows plant performance for 2013 and averages for four three-year periods.
PRODUCTION COST ($/MWh)(a)	2013	2010-2012	2009–2011	2008–2010	2007–2009
ANO	22.9	20.6	19.8	18.5	17.2
Grand Gulf	25.9	23.1	19.8	18.8	17.7
River Bend	27.3	24.6	23.2	23.4	22.9
Waterford 3	25.1	22.2	20.8	19.3	18.1
Entergy Southeast Average	25.1	22.3	20.6	19.6	18.5
Industry Average	—	22.9	21.7	20.4	19.4
(a) Fuel and non-fuel operation and maintenance expenses according to accounting standards that directly relate to the production of electricity per MWh;
includes special items to conform with FERC Form 1 definition
INDIVIDUAL PLANT INFORMATION
	ANO		GRAND GULF	RIVER BEND	WATERFORD 3
	UNIT 1	UNIT 2
Owner	Entergy	Entergy	System Energy-90%	Entergy	Entergy
	Arkansas	Arkansas	South Mississippi	Gulf States	Louisiana
			Electric Power	Louisiana
			Association-10%
Commercial Operation Date	December 74	March 80	July 85	June 86	September 85
License Expiration Date	5/20/34	7/17/38	11/1/24	8/29/25	12/18/24
Architect/Engineer	Bechtel Power	Bechtel Power	Bechtel Power	Stone & Webster	Ebasco
Reactor Manufacturer	Babcox &	Combustion	General	General	Combustion
	Wilcox	Engineering	Electric	Electric	Engineering
Reactor Type	PWR	PWR	BWR	BWR	PWR
Turbine Generator Manufacturer	Westinghouse	General Electric	Kraftwerk Union	General Electric	Westinghouse
Owned and Leased Capability (MW)(a)	834	985	1,272	968	1,156
Refueling Data:
Last Date	3/24/13 -	5/11/14  -	2/9/14 -	2/17/13 -	4/13/14 -
	8/7/13	6/12/14	3/16/14	3/20/13	5/14/14
Number of Days	136(d)	32	34	31	32
Next Scheduled Refueling	Spring 15	Fall 15	Spring 16	Spring 15	Fall 15
2013 Capability Factor (%)	73.8	85.1	74.6	90.0	80.7
($ millions as of December 31, 2013)
Net Book Value	1,200(b)		1,869	1,446(c)	2,055
Decommissioning Trust Fair Values	711(b)		604	574(c)	347
Decommissioning Liability	715(b)		465	392(c)	616
(a) Owned and Leased Capability is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel
(assuming no curtailments) that each station was designed to utilize.
(b) ANO Units 1 and 2 are reported together.
(c) 30% of River Bend is not subject to rate regulation by the Public Utility Commission of Texas, the Louisiana Public Service Commission, nor various
municipal authorities, and is included in non-utility property on the balance sheet. The decommissioning trust fund balance and decommissioning liability
include amounts for the 30% not subject to rate regulation.
(d) On March 31, 2013, during a scheduled refueling outage at ANO 1, a contractor-owned and operated heavy-lifting apparatus collapsed while moving the generator
stator out of the turbine building. The collapse damaged the ANO turbine building. The outage duration reflects extensive restoration efforts, including damage evaluation
repairs to non-reactor plant components and rescheduling the unit’s refueling activities.

 

UTILITY REGULATORY INFORMATION
STATE REGULATORY COMMISSIONS
	ARKANSAS	LOUISIANA	MISSISSIPPI	NEW ORLEANS	TEXAS
Commission	Arkansas Public	Louisiana	Mississippi	New Orleans	Public Utility
	Service	Public Service	Public Service	City Council	Commission
	Commission	Commission	Commission		of Texas
Number of Commissioners	3	5	3	7	3
Method of Selection	Appointed by	Elected	Elected	Elected	Appointed by
	Governor				Governor
Term of Office	6 years –	6 years –	4 years –	4 years –	6 years –
	staggered	staggered	concurrent	concurrent	staggered
				(2 term limit)
Chair/President	Appointed by	Selected by	Rotates every	Rotates annually	Appointed by
	Governor	peers – 1 year	1 - 2 years, as	from the	Governor
		term	determined by members	at-large positions
COMMISSION/COUNCIL MEMBERS
					CURRENT
			PARTY	SERVICE BEGAN	TERM ENDS
ARKANSAS
Colette Honorable – Chair			Democrat	10/07	1/17
Olan W. Reeves			unknown	1/09	1/15
Elana C. Wills			unknown	1/11	1/13(a)
LOUISIANA
Foster L. Campbell, Jr.			Democrat	1/03	12/14
Scott A. Angelle			Republican	1/13	12/18
Lambert C. Boissiere, III			Democrat	1/05	12/16
Eric Skrmetta – Chairman			Republican	1/09	12/14
Clyde C. Holloway			Republican	4/09	12/16
MISSISSIPPI
Lynn Posey – Chairman (2013)			Republican	1/08	12/15
R. Stephen Renfroe – Vice-Chairman (2013)			Republican	9/13	12/15
Brandon Presley			Democrat	1/08	12/15
NEW ORLEANS
Stacy Head			Democrat	5/06	5/18
Jason Rogers Williams - Chair of Utility Committee			Democrat	5/14	5/18
Susan Guidry			Democrat	5/10	5/18
LaToya Cantrell			Democrat	12/12	5/18
Nadine Ramsey			Democrat	5/14	5/18
Jared Brossett			Democrat	5/14	5/18
James Gray II			Democrat	12/12	5/18
TEXAS
Donna L. Nelson – Chair			Republican	8/08	8/15
Kenneth W. Anderson Jr.			Republican	9/08	8/17
Brandy D. Marty			Republican	8/13	9/19
(a) Commissioner Wills' term has expired, however no one has been appointed to replace her yet; she will serve until she is replaced

UTILITY ELECTRIC AND GAS FUEL RECOVERY MECHANISMS
	DEFERRED FUEL* BALANCE AS OF DECEMBER  31,
COMPANY	2013	2012	2011	2010	2009	FUEL RECOVERY MECHANISM
				($ millions)
EAI	68.7	97.3	209.8	61.5	122.8	Annual reset in April based on prior calendar year fuel and purchased power costs adjusted for
						nuclear refueling outages and projected sales plus any under- or over-recovered fuel balance
						for the prior calendar year.
EGSL(a)	109.7	99.2	2.9	77.8	57.8	Electric: Monthly reset based on fuel and purchased power costs from two months prior
						plus surcharge or credit for 1/12 of under- or over-recovered fuel balance.
						Gas: Monthly reset based on estimated gas costs plus a surcharge with an annual reset calculated
						by taking the over- or under- recovered balance at the end of June and dividing by the
						projected sales for the next 12 months.
ELL(a)	37.6	94.6	1.5	8.8	66.4	Monthly reset based on fuel and purchased power costs from two months prior plus surcharge
						or credit for 1/12 of under- or over-recovered fuel balance.
EMI	38.1	26.5	(15.8)	3.2	(72.9)	Annual reset based on projected fuel and purchased power costs and projected sales plus any
						under- or over-recovered energy costs as of the 12-month period ended September 30.
ENOI(a)	(19.1)	1.9	(7.5)	(2.8)	8.1	Electric: On April 2, 2009 the New Orleans City Council approved a new Fuel Adjustment Clause tariff
						that calculates a monthly rate based on fuel and purchased power costs from two months prior.
						A surcharge or credit will be calculated on any under- or over-recovered fuel balance based on the
						most recent 12 months actual kWh sales.  Under the new tariff Grand Gulf non-fuel costs are
						recovered through base rates.  Any incremental monthly Grand Gulf non-fuel costs are included in
						the Fuel Adjustment Clause.  Resource Plan non-fuel costs are collected through the Fuel
						Adjustment Clause.  The new tariff became effective on June 1, 2009.
						Gas: Monthly reset based on estimated gas costs plus a surcharge or credit for the under- or
						over-recovered fuel balance based on the most recent 12 months Mcf sales.
ETI	(4.1)	(93.3)	(64.7)	(77.4)	(102.7)	Semi-annual reset of fuel factor in March and September based on the market price of natural gas
						plus surcharge or refund for material under- or over-recoveries based on actual costs.
Total	230.9	226.2	126.2	71.1	79.5
Totals may not foot due to rounding.
(a) All years include $100.1 million for Entergy Gulf States Louisiana, $68 million for Entergy Louisiana and $4.1 million for Entergy New Orleans of fuel, purchased power, and capacity
costs, which do not currently earn a return on investment and whose recovery periods are indeterminate but are expected to be over a period greater than twelve months.
* Deferred fuel costs = revenues collected minus current fuel and purchased power costs; amount includes rough production cost equalization payments/receipts due to/from
customers for EAI, ETI and ENOI

ENTERGY WHOLESALE COMMODITIES
EWC QUARTERLY FINANCIAL METRICS
	2013					2012
	1Q	2Q	3Q	4Q	YTD	1Q	2Q	3Q	4Q	YTD	% CHANGE
GAAP MEASURES
As-Reported Net Income ($ millions)	82.1	11.5	(92.8)	42.1	42.9	(175.9)	70.8	86.8	58.8	40.4	6
Return on Average Invested Capital – As-Reported (%)*	5.5	4.5	1.3	1.0	1.0	3.9	3.4	2.7	0.9	0.9	11
Return on Average Common Equity – As-Reported (%)*	5.5	4.4	1.1	0.9	0.9	3.9	3.3	2.7	0.8	0.8	13
Debt to Capital Ratio (%)	2.0	2.0	5.7	4.0	4.0	3.7	2.5	2.4	2.1	2.1	90
NON-GAAP MEASURES
Operational Adjusted EBITDA ($ millions)	194	61	165	133	553	144	127	185	161	618	(11)
Operational Earnings ($ millions)	82.1	12.7	82.3	85.6	262.7	47.5	70.8	86.8	58.8	263.9	-
Return on Average Invested Capital – Operational (%)*	5.5	4.5	4.5	5.3	5.3	7.9	7.4	6.7	5.0	5.0	6
Return on Average Common Equity – Operational (%)*	5.5	4.4	4.5	5.3	5.3	8.2	7.6	7.0	5.0	5.0	6
Net Debt to Net Capital Ratio (%)	(1.0)	(0.5)	3.5	0.5	0.5	(1.0)	0.6	(1.2)	(0.6)	(0.6)	(183)
*Rolling twelve months.
Certain prior year data has been reclassified to conform with current year presentation.
Totals may not foot due to rounding.
EWC ANNUAL FINANCIAL METRICS
			2013		2012		2011		2010		2009
GAAP MEASURES
As-Reported Net Income ($ millions)			42.9		40.4		488.6		447.4		606.7
Return on Average Invested Capital – As-Reported (%)			1.0		0.9		9.1		9.5		13.7
Return on Average Common Equity – As-Reported (%)			0.9		0.8		9.7		10.5		16.9
Debt to Capital Ratio (%)			4.0		2.1		3.6		15.3		23.7
NON-GAAP MEASURES
Operational Adjusted EBITDA ($ millions)			553		618		862		1,048		1,230
Operational Earnings ($ millions)			262.7		263.9		488.6		548.1		650.7
Return on Average Invested Capital – Operational (%)			5.3		5.0		9.1		11.4		14.6
Return on Average Common Equity – Operational (%)			5.3		5.0		9.7		12.9		18.1
Net Debt to Net Capital Ratio (%)			0.5		(0.6)		(2.2)		7.8		16.4
Certain prior year data has been reclassified to conform with current year presentation.
EWC QUARTERLY OPERATIONAL METRICS
	2013					2012					YTD
	1Q	2Q	3Q	4Q	YTD	1Q	2Q	3Q	4Q	YTD	% CHANGE
Owned Capacity (MW)	6,612	6,612	6,612	6,068	6,068	6,612	6,612	6,612	6,612	6,612	(8)
Average Realized Revenue/MWh	$   58.66	$   47.36	$  53.22	$    45.05	$  50.86	$    49.29	$  48.27	$  51.88	$      50.56	$  50.02	2
Non-Fuel O&M Expense per MWh(a)	$   25.22	$   25.69	$  25.28	$    25.10	$  25.32	$    23.93	$  24.07	$  23.15	$      23.52	$  23.66	7
Billed GWh	10,387	11,172	11,630	11,938	45,127	11,281	11,674	12,002	11,221	46,178	(2)
EWC Nuclear
Average Realized Revenue/MWh	$   57.82	$   46.40	$  53.16	$    44.15	$  50.15	$    50.32	$  48.67	$  52.27	$      49.88	$  50.29	(0)
Production Cost/MWh	$   25.94	$   29.16	$  25.32	$    25.37	$  26.35	$    25.85	$  26.61	$  26.14	$      26.18	$  26.19	1
Non-Fuel O&M Expense per MWh	$   27.40	$   28.28	$  27.39	$    26.82	$  27.45	$    26.37	$  25.59	$  25.46	$      24.44	$  25.45	8
Billed GWh	9,246	9,789	10,274	10,858	40,167	9,838	10,426	10,480	10,298	41,042	(2)
Capacity Factor	83%	82%	94%	97%	89%	88%	85%	90%	90%	89%	-
(a) 2012 and 2013 exclude the effect of the special item for the Vermont Yankee asset impairment/related charges; 2013 excludes the effect of the special item for HCM implementation expenses
Certain prior year data has been reclassified to conform with current year presentation.
Totals may not foot due to rounding.
EWC ANNUAL OPERATIONAL METRICS
			2013		2012		2011		2010		2009
Owned Capacity (MW)			6,068		6,612		6,599		6,351		6,351
Average Realized Revenue/MWh			$  50.86		$  50.02		$  54.50		$      59.04		$       60.46
Non-Fuel O&M Expense per MWh(a)(b)			$  25.32		$  23.66		$  24.28		$      26.76		$       24.45
Billed GWh			45,127		46,178		43,497		42,682		43,969
EWC Nuclear
Net MW in Operation			5,011		5,011		4,998		4,998		4,998
Average Realized Price/MWh			$  50.15		$  50.29		$  54.73		$      59.16		$       61.07
Production Cost/MWh(b)			$  26.35		$  26.19		$  25.21		$      25.27		$       23.26
Non-Fuel O&M Expense per MWh(a)(b)			$  27.45		$  25.45		$  25.25		$      25.66		$       22.92
Billed GWh			40,167		41,042		40,918		39,655		40,981
Capacity Factor			89%		89%		93%		90%		93%
(a) 2010 and 2009 exclude the effects of the non-utility nuclear spin-off expenses special items at EWC Nuclear.
(b) 2012 and 2013 exclude the effect of the special item for the Vermont Yankee asset impairment/related charges; 2013 excludes the effect of the special item for HCM implementation expenses
Certain prior year data has been reclassified to conform with current year presentation.
Totals may not foot due to rounding.
TOTAL CAPACITY
		OPERATED						OWNED CAPACITY
As of December 2013.		PLANTS	UNITS	MW					MW	%
Gas/Oil (c)		1	3	583(b)					796	13
Coal		-	-	-					181	3
Total Fossil		1	3	583					977	16
Wind		-	-	-					80	1
Nuclear		6	7	5,811(a)					5,011	83
Total Capacity		7	10	6,394					6,068	100
(a) Operated capacity includes management services contracts.
(b) Excludes units operated by Entergy’s utility companies.
(c) In November 2013, Ritchie Unit 2 (gas/oil) plant was retired (544 MWs)

ENTERGY WHOLESALE COMMODITIES
EWC NUCLEAR PLANT STATISTICS
	JAMES A.	INDIAN POINT		PALISADES	PILGRIM	VERMONT
	FITZPATRICK	UNIT 2	UNIT 3	NUCLEAR PLANT	NUCLEAR STATION	YANKEE(f)
Entergy Purchase Date	11/21/00	9/6/01	11/21/00	4/11/07	7/13/99	7/31/02
Commercial Operation Date	July 75	August 74	August 76	December 71	December 72	November 72
License Expiration Date	10/17/34	9/28/13 (g)	12/12/15	3/24/31	6/8/32	3/21/32
Architect/Engineer	Stone &	United	United	Combustion	Bechtel	Ebasco
	Webster	Engineers &	Engineers &	Engineering	Power
		Constructors	Constructors
Reactor Manufacturer	General	Westinghouse	Westinghouse	Combustion	General	General
	Electric			Engineering	Electric	Electric
Reactor Type	BWR	PWR	PWR	PWR	BWR	BWR
Turbine Generator Manufacturer	General Electric	Westinghouse	Westinghouse	Westinghouse	General Electric	General Electric
Net MWs in Operation (MW)	838	1,028	1,041	811	688	605
(as of December 31, 2013)
Refueling Data:
Last Date	9/16/12 –	2/24/14 –	3/4/13 –	1/19/14 –	4/14/13 –	3/9/13 –
	10/19/12	3/19/14	3/31/13	3/16/14	5/30/13	4/5/13
Number of Days	34	23	28	56	45	27
Next Scheduled Refueling	Late Summer 14	Spring 16	Spring 15	Fall 15	Spring 15	n/a
2013 Capacity Factor	92%	98%	91%	86%	73%	91%
Spent Fuel Storage Thru	2002	2006	2009	1991	2015	n/a
Begin Dry Cask Loading	2002	2007	2010	1993	2014	n/a
($ millions as of December 31, 2013)
Net Book Value	569	896	924	782	359	29 (e)
Decommissioning Trust Fund Balance	(a)	876 (b)	(a)	354	825	612
Decommissioning Liability	(a)	511 (b)	(a)	353	355	478
Nearest Market Hub	NYISO	NYISO	NYISO	MISO	NEPOOL	NEPOOL
	Zone A(c)	Zone G(d)	Zone G(d)	Indiana	Mass Hub	Mass Hub
Capacity Zone (ICAP/UCAP)	NYISO	NYISO	NYISO	MISO	NEPOOL	NEPOOL
	Rest of State	Lower Hudson Valley	Lower Hudson Valley
(a) NYPA retained the decommissioning trusts and decommissioning liability. NYPA and Entergy executed decommissioning agreements, specifying their decommissioning
obligations. NYPA has the right to require Entergy to assume the decommissioning liability provided that it assigns the corresponding decommissioning trust, up to a specified
level, to Entergy. If the decommissioning liability is retained by NYPA, Entergy will perform the decommissioning of the plants at a price equal to the lesser of a pre-specified
level or the amount in the decommissioning trusts. Entergy believes that the amounts available to it under either scenario are sufficient to cover the future decommissioning
costs without any additional contributions to the trusts.
(b) Includes amount for Indian Point 1. Indian Point 1 has been shut down and in safe storage since the 1970s.
(c) James A. FitzPatrick physically located in NYISO Zone C.
(d) Indian Point physically located in NYISO Zone H.
(e) Reflects $321.5 million ($202.2 million after-tax) in 2013 and $355.5 million ($223.5 million after-tax) in 2012 of impairment and other related
charges to write down the carrying value of Vermont Yankee and related assets to their fair values. See pgs. 66 - 68 of the 2013 10-K for more detail.
(f) Entergy plans to close the Vermont Yankee plant at the end of its current operating cycle in fourth quarter 2014.
(g) On 9/28/13, Indian Point 2 entered the period of extended operations under its current license.
EWC NON-NUCLEAR WHOLESALE ASSETS PLANT STATISTICS
		NERC	COMMERCIAL	OWNERSHIP	NET	TOTAL	FUEL TYPE
PLANT (a)	LOCATION	REGION	OPERATION	INTEREST	MW	MW	TECHNOLOGY
Independence – Unit 2	Newark, AR	SERC	1983	14%	121	842	Coal
Nelson 6	Westlake, LA	SERC	1982	11%	60	550	Coal
RS Cogen	Lake Charles, LA	SERC	2002	50%	213	425	CCGT Cogen
Top of Iowa	Worth County, IA	MRO	2001	50%	40	80	Wind
White Deer	Amarillo, TX	SPP	2001	50%	40	80	Wind
Rhode Island State Energy Center	Johnston, RI	NPCC	2002	100%	583	583	CCGT
Total					1,057	2,560
(a) In November 2013, Ritchie Unit 2 (gas/oil) plant was retired (544 MWs)
EWC NON-NUCLEAR WHOLESALE ASSETS PLANT EMISSIONS
			Emissions
	FUEL TYPE		SO2	NOx	CO2	Hg(a)
PLANT (c)	TECHNOLOGY	PURPOSE	(tons)	(tons)	(tons)	(lbs)	TECHNOLOGY(b)
Independence – Unit 2	Coal	Base	6,407	2,353	2,425,422	124	OFA
Nelson 6	Coal	Base	9,267	2,264	2,966,451	146	LNB w Sep OFA
RS Cogen	CCGT Cogen	Base	9	801	1,777,171	0	Dry LNB/SCR
Top of Iowa	Wind	Renewable	-	-	-	-	-
White Deer	Wind	Renewable	-	-	-	-	-
Rhode Island State Energy Center	CCGT	Intermediate	4	59	840,852	0	Dry LNB/SCR
Total			15,687	5,477	8,009,897	270
(a) Mercury emissions calculated using 2013 unit heat input and 5.37 x 10-6 lb hg/MMBtu emission rate for coal plants and 8.0 x 10-10 lb hg/MMBtu emission rate for natural gas plants.
(b) Installed NOx and particulate matter emission control devices: Combustion Modification/ Fuel Reburning (Combus Mod / Fuel Reburn), Dry Low NOx Burners (Dry LNB), Electrostatic Precipitator (ESP),
Low NOx Burners with Closed-coupled Overfire Air (LNB w/ Closed-coupled OFA), Low NOx Burners with Separated Overfire Air (LNB w/ Sep OFA), Low NOx Burner with Overfire Air (LNB w/ OFA),
Overfire Air (OFA), Selective Catalytic Reduction (SCR) or Steam Injection.  Currently have no SO2, CO2 or Mercury Control equipment operating on any unit.
(c) In November 2013, Ritchie Unit 2 (gas/oil) plant was retired (544 MWs)
Totals may not foot due to rounding.

ENTERGY WHOLESALE COMMODITIES
EWC NUCLEAR SECURITIES DETAIL
LONG-TERM DEBT:
NOTE TO NEW YORK POWER AUTHORITY (NYPA) RELATING TO THE PURCHASE OF FITZPATRICK AND INDIAN POINT 3
			ADDITIONAL LTD			TOTAL ENDING		TOTAL
		INTEREST	RELATED TO	INTEREST		LONG-TERM		INTEREST
($ thousands)	LONG-TERM DEBT(a)	EXPENSE	PURCHASE OF IP2	EXPENSE		DEBT		EXPENSE
2000	744,405	3,869	-	-		744,405		3,869
2001	682,512	35,392	74,402	1,190		756,914		36,582
2002	604,420	32,540	79,220	3,628		683,640		36,168
2003	441,845	27,387	72,863	3,643		514,708		31,030
2004	379,405	21,275	66,200	3,337		445,605		24,612
2005	313,968	18,277	59,218	3,018		373,186		21,295
2006	245,390	15,137	51,900	2,682		297,289		17,819
2007	173,445	11,845	44,231	2,331		217,676		14,176
2008	161,932	8,412	36,194	1,963		198,127		10,375
2009	149,771	7,839	27,772	1,577		177,543		9,416
2010	137,026	7,255	18,945	1,173		155,971		8,428
2011	123,669	6,643	9,694	750		133,363		7,393
2012	109,681	6,012	-	305		109,681		6,317
2013	95,011	5,331	-	-		95,011		5,331
2014	79,638	4,627	-	-		79,638		4,627
2015	61,027	3,889	-	-		61,027		3,889
2016	59,022	2,995	-	-		59,022		2,995
2017	56,921	2,899	-	-		56,921		2,899
2018	54,719	2,798	-	-		54,719		2,798
2019	52,412	2,693	-	-		52,412		2,693
2020	49,994	2,582	-	-		49,994		2,582
2021 – 2035 Average	-	1,400	-	-		-		1,400
(a) Includes plant, fuel, and license extension payments. Payments for plant and fuel are made annually on 11/21 (anniversary of close). As of 9/30/03, the entire fuel note
has been paid off.  Life extension payments made on anniversary of license expiration. Entergy will pay NYPA $2.5 million annually per plant, for up to twenty years if
FitzPatrick and/or Indian Point 3 operate beyond their original license date.
Totals may not foot due to rounding.
EWC NON-NUCLEAR WHOLESALE ASSETS
EWC NON-NUCLEAR WHOLESALE ASSETS SECURITIES DETAIL
DEBT:
OUTSTANDING AS OF DECEMBER 31,
(ENTERGY’S SHARE)		2013	2012	2011		MATURITY		RATE
			(in millions)
RS Cogen Senior Project Debt
Bank Portion(a)		$31	$36	$40		10/17/18		LIBOR + 1.625%
Institutional Portion		$38	$38	$38		10/15/22		Fixed 8.73%
RS Cogen Subordinated Debt(b)		$18	$16	$16		10/17/17		LIBOR + 4.50%
(a) RS Cogen spread on bank portion increases over time from 1.375% to 2.375%.
(b) Debt outstanding includes Entergy's portion of accrued but unpaid interest on Entergy's portion of the RS Cogen subordinated debt since the project went into default
on the subordinated credit facility in 2008
			SHARES OUTSTANDING
PREFERRED STOCK:			AS OF DECEMBER 31,			AS OF DECEMBER 31,
		RATE	2013	2012	2011	2013	2012	2011
							(in millions)
Without Sinking Fund:
Entergy Asset Management		8.95%(a)	-	-	-	-	-	-
Authorized 1,000,000 shares, $1 par value, cumulative
Entergy Finance Holding, Inc.		8.75%(b)	250,000	-	-	$              24.2	-	-
Authorized 250,000 shares, $100 par value, cumulative
Total without sinking fund			250,000	-	-	$              24.2	$   -	-
(a) Upon the sale of Class B preferred shares in December 2009, Entergy Asset Management had issued and outstanding Class A and Class B preferred shares. On
December 20, 2011, Entergy Asset Management purchased all of the outstanding Class B preferred shares from the holder thereof; currently, there are no outstanding
Class B preferred shares. On December 20, 2011, Entergy Asset Management purchased all of the outstanding Class A preferred shares (278,905 shares) that were held
by a third party; currently, there are 4,759 shares held by an Entergy affiliate.
(b) Dollar amount outstanding is net of $751 thousand of preferred stock issuance costs.
Totals may not foot due to rounding.

DEFINITIONS OF OPERATIONAL MEASURES AND GAAP AND NON-GAAP FINANCIAL MEASURES
ENTERGY WHOLESALE COMMODITIES OPERATIONAL MEASURES
Owned capacity (MW)	Installed capacity owned and operated by EWC, including investments in wind generation accounted for under the equity method of accounting; in November 2013, R.E. Ritchie Unit 2 (gas/oil) plant was retired (544 MWs)
Average realized revenue per MWh	As-reported revenue per MWh billed, excluding revenue from the amortization of the Palisades below-market PPA and/or investments in wind generation accounted for under the equity method of accounting
Non-fuel O&M per MWh	Operation, maintenance and refueling expenses per MWh billed, excluding fuel, fuel-related expenses and  purchased power, special items and investments in wind generation accounted for under the equity method of accounting
Production cost per MWh	Fuel and non-fuel O&M expenses according to accounting standards that directly relate to the production of  electricity per MWh (based on net generation)
GWh billed	Total number of GWh billed to customers, excluding investments in wind generation accounted for under  the equity method of accounting and financially-settled instruments
Capability factor	The percentage of the maximum energy generation a plant is capable of supplying to the grid, limited
	only by factors within control of plant management; a high capability factor indicates effective plant
	programs and practices to minimize unplanned energy losses and to optimize planned outages
Capacity factor	Normalized percentage of the period that the nuclear plants generate power
Refueling outage days	Number of days lost for scheduled refueling outage during the period
Financial measures defined below include measures prepared in accordance with generally accepted accounting principles (GAAP), as well as non-
GAAP measures. Non-GAAP measures are included in this report in order to provide metrics that remove the effect of less routine financial impacts from
commonly used financial metrics.
FINANCIAL MEASURES – GAAP
Return on average invested capital – as-reported	12-months rolling net income attributable to Entergy Corporation or Subsidiary (Net Income) adjusted to include preferred
	dividends and tax-effected interest expense divided by average invested capital
Return on average common equity – as-reported	12-months rolling Net Income divided by average common equity
Cash flow interest coverage	12-months cash flow from operating activities plus 12-months rolling interest paid, divided by interest expense
Book value per share	Common equity divided by end of period shares outstanding
Revolver capacity	Amount of undrawn capacity remaining on corporate and subsidiary revolvers
Total debt	Sum of short-term and long-term debt, notes payable and commercial paper and capital leases on the balance sheet
Debt of joint ventures - Entergy’s share	Debt issued by business joint ventures at EWC
Leases - Entergy’s share	Operating leases held by subsidiaries capitalized at implicit interest rate
Debt to capital ratio	Total debt divided by total capitalization
Securitization debt	Debt associated with securitization bonds issued to recover storm costs from hurricanes Rita, Ike and Gustav
	at Entergy Texas; the 2009 ice storm at Entergy Arkansas; and investment recovery of costs
	associated with the cancelled Little Gypsy repowering project at Entergy Louisiana
Assumption debt	Represents the portion of Entergy Gulf States Louisiana long-term debt that was outstanding on December 31, 2007,
	which was assumed by Entergy Texas under a debt assumption agreement. Entergy Texas' pro rata share of the debt
	was approximately 46 percent
FINANCIAL MEASURES – NON-GAAP
Operational earnings	As-reported Net Income adjusted to exclude the impact of special items
Operational adjusted EBITDA	Earnings before interest, income taxes, depreciation and amortization, and interest and investment income
	excluding decommissioning expense, and other than temporary impairment losses on decommissioning trust
	fund assets, excluding effects of special items
Return on average invested capital – operational	12-months rolling operational Net Income adjusted to include preferred dividends and
	tax-effected interest expense divided by average invested capital
Return on average common equity – operational	12-months rolling operational Net Income divided by average common equity
Gross liquidity	Sum of cash and revolver capacity
Debt to capital ratio, excluding securitization debt	Total debt divided by total capitalization, excluding securitization debt
Net debt to net capital ratio, excluding securitization debt	Total debt less cash and cash equivalents divided by total capitalization less cash and
	cash equivalents, excluding securitization debt
Net debt to net capital ratio, including off-balance sheet liabilities, excluding securitization debt	Sum of total debt and off-balance sheet debt less cash and cash equivalents divided by sum of  total capitalization and off-balance sheet debt less cash and cash equivalents, excluding securitization debt
Total debt, excluding assumption debt	Gross debt less assumption debt
Debt to capital ratio, excluding assumption debt	Gross debt divided by total capitalization, excluding assumption debt
Net debt to net capital ratio, excluding assumption debt	Gross debt less cash and cash equivalents divided by total capitalization less cash and cash equivalents,  excluding assumption debt

REG G RECONCILIATIONS
CONSOLIDATED FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011		2010		2009
As-Reported Net Income (A)	712		847		1,346		1,250		1,231
Preferred dividends	19		22		21		20		20
Tax-effected interest expense	371		350		316		354		351
As-Reported Net Income including preferred
dividends and tax-effected interest expense (B)	1,102		1,219		1,683		1,624		1,602
Special items (C)	(245	)	(262	)	(13	)	(82	)	(71	)
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	1,347		1,481		1,696		1,706		1,673
Operational earnings (A-C)	957		1,109		1,359		1,332		1,302
Average invested capital (D)	23,283		22,290		21,126		20,781		20,748
Average common equity (E)	9,415		9,079		8,729		8,555		8,290
Gross debt (F)	13,678		13,473		12,387		11,816		12,014
Less securitization debt (G)	883		973		1,071		931		838
Gross debt, excluding securitization debt (F-G)	12,795		12,500		11,316		10,885		11,176
Less cash and cash equivalents (H)	739		533		694		1,294		1,710
Net debt, excluding securitization debt (F-G-H)	12,056		11,967		10,622		9,591		9,466
Total capitalization (I)	23,615		22,951		21,629		20,623		20,939
Less securitization debt (J)	883		973		1,071		931		838
Total capitalization, excluding securitization debt (I-J)	22,732		21,978		20,558		19,692		20,101
Less cash and cash equivalents (K)	739		533		694		1,294		1,710
Net capitalization, excluding securitization debt (I-J-K)	21,993		21,445		19,864		18,398		18,391
Off-balance sheet liabilities (L)	542		595		602		653		646
Revolver capacity (M)	3,977		3,462		2,001		2,354		1,464
Gross liquidity (H+M)	4,716		3,995		2,695		3,648		3,174
($ per share)
As-Reported earnings per share (N)	3.99		4.76		7.55		6.66		6.30
Operational earnings per share (O)	5.36		6.23		7.62		7.10		6.67
Common dividend paid per share (P)	3.32		3.32		3.32		3.24		3.00
Year-end closing market price per share of common stock (Q)	63.27		63.75		73.05		70.83		81.84
(%)
Return on average invested capital – As-Reported (B/D)	4.7		5.5		8.0		7.8		7.7
Return on average invested capital – Operational ((B-C)/D)	5.8		6.6		8.0		8.2		8.1
Return on average common equity – As-Reported (A/E)	7.6		9.3		15.4		14.6		14.9
Return on average common equity – Operational ((A-C)/E)	10.2		12.2		15.6		15.6		15.7
Debt to capital ratio (F/I)	57.9		58.7		57.3		57.3		57.4
Debt to capital ratio, excluding securitization debt ((F-G)/(I-J))	56.3		56.9		55.0		55.3		55.6
Net debt to net capital ratio, excluding securitization debt ((F-G-H)/(I-J-K))	54.8		55.8		53.5		52.1		51.5
Net debt to net capital ratio including off-balance sheet liabilities,
excluding securitization debt ((F-G-H+L)/(I-J-K+L))	55.9		57.0		54.8		53.8		53.1
Common dividend payout ratio – As-Reported (P/N)	83		70		44		49		48
Common dividend payout ratio – Operational (P/O)	62		53		44		46		45
Price to earnings ratio – As-Reported (Q/N)	15.87		13.39		9.68		10.64		12.99
Price to earnings ratio – Operational (Q/O)	11.80		10.23		9.59		9.98		12.27
Calculations may differ due to rounding.

REG G RECONCILIATIONS
CONSOLIDATED FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
1Q12-4Q13
($ millions)	1Q13		2Q13		3Q13		4Q13		1Q12		2Q12		3Q12		4Q12
For the quarter:
As-Reported Net Income (A)	161.4		163.7		239.9		146.9		(151.7	)	365.0		337.1		296.3
Less special items (B)	(6.3	)	(16.0	)	(190.5	)	(32.4	)	(230.7	)	(9.6	)	(10.7	)	(10.7	)
Operational earnings (A-B)	167.7		179.7		430.4		179.3		79.0		374.6		347.8		307.1
As-Reported Net Income rolling 12 months (C)	1,160		958		861		712		946		996		705		847
Preferred dividends	22		21		20		19		21		21		22		22
Tax-effected interest expense	356		363		365		371		322		329		342		350
As-Reported Net Income,
rolling 12 months including
preferred dividends and tax-effected
interest expense (D)	1,538		1,342		1,246		1,102		1,289		1,346		1,069		1,219
Special items in prior quarters	(31.0	)	(27.7	)	(33.0	)	(212.8	)	(13	)	(244	)	(253	)	(251	)
Special items in current quarter
HCM implementation expenses	-		(3.8	)	(7.3	)	(26.1	)	-		-		-		-
Transmission business spin-merge expenses	(6.3	)	(12.2	)	(10.1	)	25.5		(5.8	)	(9.9	)	(10.7	)	(10.7	)
VY asset impairments/related charges	-		-		(173.1	)	(31.8	)	(224	)	-		-		-
Total special items (E)	(37.3	)	(43.7	)	(223.5	)	(245.2	)	(243	)	(254	)	(264	)	(262	)
Operational earnings,
rolling 12 months including
preferred dividends and tax-effected
interest expense (D-E)	1,574		1,386		1,470		1,347		1,532		1,600		1,333		1,481
Operational earnings, rolling 12 months (C-E)	1,196		1,002		1,085		957		1,189		1,250		969		1,109
Average invested capital (F)	22,389		22,573		22,857		23,283		21,339		21,556		22,065		22,290
Average common equity (G)	9,064		9,152		9,299		9,415		8,725		8,814		9,078		9,079
Gross debt (H)	13,471		13,747		13,623		13,678		12,619		12,533		12,931		13,473
Less securitization debt (I)	952		927		910		883		1,049		1,020		1,003		973
Gross debt, excluding securitization debt (H-I)	12,519		12,820		12,713		12,795		11,570		11,513		11,928		12,500
Less cash and cash equivalents (J)	263		311		365		739		685		283		750		533
Net debt, excluding securitization debt (H-I-J)	12,256		12,509		12,348		12,056		10,885		11,230		11,178		11,967
Total capitalization (K)	22,965		23,302		23,312		23,615		21,813		21,844		22,402		22,951
Less securitization debt (L)	952		927		910		883		1,049		1,020		1,003		973
Total capitalization, excluding securitization debt (K-L)	22,013		22,375		22,402		22,732		20,764		20,824		21,399		21,978
Less cash and cash equivalents (M)	263		311		365		739		685		283		750		533
Net capitalization, excluding securitization debt (K-L-M)	21,750		22,064		22,037		21,993		20,079		20,541		20,649		21,445
Off-balance sheet liabilities (N)	595		594		592		542		601		600		599		595
Revolver capacity (O)	3,542		3,819		4,129		3,977		2,825		2,762		2,917		3,462
Gross liquidity (J+O)	3,805		4,130		4,494		4,716		3,510		3,045		3,667		3,995
(%)
Return on average invested capital – As-Reported (D/F)	6.9		5.9		5.5		4.7		6.0		6.2		4.8		5.5
Return on average invested capital – Operational ((D-E)/F)	7.0		6.1		6.4		5.8		7.2		7.4		6.0		6.6
Return on average common equity – As-Reported (C/G)	12.8		10.5		9.3		7.6		10.8		11.3		7.8		9.3
Return on average common equity – Operational ((C-E)/G)	13.2		10.9		11.7		10.2		13.6		14.2		10.7		12.2
Debt to capital ratio (H/K)	58.7		59.0		58.4		57.9		57.9		57.4		57.7		58.7
Debt to capital ratio, excluding securitization debt ((H-I)/(K-L))	56.9		57.3		56.7		56.3		55.7		55.3		55.7		56.9
Net debt to net capital ratio,  excluding securitization debt ((H-I-J)/(K-L-M))	56.3		56.7		56.0		54.8		54.2		54.7		54.1		55.8
Net debt to net capital ratio including off-balance
sheet liabilities, excluding securitization debt  ((H-I-J+N)/(K-L-M+N))	57.5		57.8		57.2		55.9		55.5		56.0		55.4		57.0
Calculations may differ due to rounding.

REG G RECONCILIATIONS
UTILITY FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011	2010	2009
As-Reported Net Income (A)	828.9		943.0		1,106.5	812.4	691.6
Preferred dividends	17.3		17.3		17.3	17.3	17.3
Tax-effected interest expense	313.1		293.1		280.4	303.4	284.3
As-Reported Net Income including preferred
dividends and tax-effected interest expense (B)	1,159.3		1,253.4		1,404.2	1,133.2	993.3
Utility special items
Transmission business spin-merge expenses	(8.7	)	(37.1	)	-	-	-
HCM implementation expenses	(20.3	)	-		-	-	-
Total special items (C)	(29.0	)	(37.1	)	-	-	-
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	1,188.3		1,290.6		1,404.2	1,133.2	993.3
Operational earnings (A-C)	857.8		980.1		1,106.5	812.4	691.6
Average invested capital (D)	19,488		18,154		16,877	16,412	15,580
Average common equity (E)	8,599		7,991		7,462	7,109	6,828
Gross debt (F)	10,784		10,433		9,332	8,937	9,107
Less securitization debt (G)	883		974		1,071	931	838
Gross debt, excluding securitization debt (F-G)	9,901		9,459		8,262	8,006	8,269
Less cash and cash equivalents (H)	551		380		360	822	1,239
Net debt, excluding securitization debt (F-G-H)	9,350		9,079		7,902	7,185	7,030
Total capitalization (I)	19,967		19,010		17,298	16,457	16,367
Less securitization debt (J)	883		974		1,071	931	838
Total capitalization, excluding securitization debt (I-J)	19,084		18,036		16,227	15,526	15,529
Less cash and cash equivalents (K)	551		380		360	822	1,239
Net capitalization, excluding securitization debt (I-J-K)	18,533		17,656		15,867	14,704	14,290
(%)
Return on average invested capital – As-Reported (B/D)	5.9		6.9		8.3	6.9	6.4
Return on average invested capital – Operational ((B-C)/D)	6.1		7.1		8.3	6.9	6.4
Return on average common equity – As-Reported (A/E)	9.6		11.8		14.8	11.4	10.1
Return on average common equity – Operational ((A-C)/E)	10.0		12.3		14.8	11.4	10.1
Debt to capital ratio (F/I)	54.0		54.9		54.0	54.3	55.6
Debt to capital ratio, excluding securitization debt ((F-G)/(I-J))	51.9		52.4		50.9	51.6	53.2
Net debt to net capital ratio, excluding securitization debt ((F-G-H)/(I-J-K))	50.5		51.4		49.8	48.9	49.2
Calculations may differ due to rounding.

REG G RECONCILIATIONS
UTILITY FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
1Q12-4Q13
($ millions)	1Q13		2Q13		3Q13		4Q13		1Q12		2Q12		3Q12		4Q12
As-Reported Net Income (A)	123.5		196.2		348.0		161.2		62.9		304.2		296.2		279.8
Less special items (B)	(6.3	)	(14.9	)	(15.3	)	7.5		(6	)	(10	)	(11	)	(11	)
Operational earnings (A-B)	129.8		211.1		363.3		153.7		68.7		314.1		306.9		290.5
As-Reported Net Income-rolling 12 months (C)	1,003.6		895.7		947.4		828.9		1,005.1		1,060.9		832.9		943.0
Preferred dividends	17.3		17.3		17.3		17.3		17.3		17.3		17.3		17.3
Tax-effected interest expense	297.2		303.4		306.6		313.1		283.8		285.3		291.2		293.1
As-Reported Net Income, rolling 12 months including preferred
dividends and tax-effected interest expense (D)	1,318.1		1,216.4		1,271.3		1,159.3		1,306.2		1,363.5		1,141.4		1,253.4
Special items in prior quarters	(31.3	)	(27.7	)	(31.9	)	(36.5	)	-		(5.8	)	(15.7	)	(26.4	)
Special items in current quarter	(6.3	)	(14.9	)	(15.3	)	7.5		(5.8	)	(9.9	)	(10.7	)	(10.7	)
Total special items (E)	(37.6	)	(42.6	)	(47.2	)	(29.0	)	(5.8	)	(15.7	)	(26.4	)	(37.1	)
Operational earnings, rolling 12 months including preferred
dividends and tax-effected interest expense (D-E)	1,355.7		1,259.0		1,318.5		1,188.3		1,312.0		1,379.2		1,167.8		1,290.6
Operational earnings, rolling 12 months (C-E)	1,041.2		938.3		994.6		857.8		1,010.9		1,076.6		859.3		980.1
Average invested capital (F)	18,200		18,684		19,048		19,488		17,092		17,340		17,845		18,154
Average common equity (G)	7,955		8,189		8,426		8,599		7,486		7,692		7,930		7,991
Gross debt (H)	10,409		10,999		10,847		10,784		9,520		9,429		9,837		10,433
Less securitization debt (I)	952		927		910		883		1,049		1,020		1,003		974
Gross debt, excluding securitization debt (H-I)	9,457		10,072		9,937		9,901		8,472		8,409		8,834		9,459
Less cash and cash equivalents (J)	98		169		235		551		416		173		545		380
Net debt, excluding securitization debt (H-I-J)	9,359		9,903		9,702		9,350		8,056		8,236		8,290		9,079
Total capitalization (K)	18,900		19,691		19,770		19,967		17,499		17,677		18,326		19,010
Less securitization debt (L)	952		927		910		883		1,049		1,020		1,003		974
Total capitalization, excluding securitization debt (K-L)	17,948		18,764		18,860		19,084		16,450		16,657		17,323		18,036
Less cash and cash equivalents (M)	98		169		235		551		416		173		545		380
Net capitalization, excluding securitization debt (K-L-M)	17,850		18,595		18,625		18,533		16,035		16,483		16,779		17,656
(%)
Return on average invested capital –
As-Reported (D/F)	7.2		6.5		6.7		5.9		7.6		7.9		6.4		6.9
Return on average invested capital –
Operational ((D-E)/F)	7.4		6.7		6.9		6.1		7.7		8.0		6.5		7.1
Return on average common equity –
As-Reported (C/G)	12.6		10.9		11.2		9.6		13.4		13.8		10.5		11.8
Return on average common equity –
Operational ((C-E)/G)	13.1		11.5		11.8		10.0		13.5		14.0		10.8		12.3
Debt to capital ratio (H/K)	55.1		55.9		54.9		54.0		54.4		53.3		53.7		54.9
Debt to capital ratio, excluding securitization debt ((H-I)/(K-L))	52.7		53.7		52.7		51.9		51.5		50.5		51.0		52.4
Net debt to net capital ratio, excluding securitization debt  ((H-I-J)/(K-L-M))	52.4		53.3		52.1		50.5		50.2		50.0		49.4		51.4
Calculations may differ due to rounding.

REG G RECONCILIATIONS
ENTERGY ARKANSAS FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011	2010	2009
As-Reported Earnings (A)	155.1		145.5		158.0	165.7	60.0
Preferred dividends	6.9		6.9		6.9	6.9	6.9
Tax-effected interest expense	54.3		49.5		49.7	54.9	54.9
As-Reported Earnings including preferred
dividends and tax-effected interest expense (B)	216.3		201.9		214.6	227.6	121.8
Special items
Transmission business spin-merge expenses	(0.4	)	(13.0	)	-	-	-
HCM implementation expenses	(2.4	)	-		-	-	-
Total special items (C)	(2.8	)	(13.0	)	-	-	-
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	219.1		214.9		214.6	227.6	121.8
Operational earnings (A-C)	157.9		158.5		158.0	165.7	60.0
Average invested capital (D)	4,050		3,665		3,460	3,385	3,291
Average invested capital, excluding securitization (E)	3,955		3,557		3,341	3,323	3,291
Average common equity (F)	1,650		1,512		1,424	1,408	1,406
Gross debt (G)	2,407		2,162		1,911	1,928	1,793
Less securitization debt (H)	89		102		114	124	-
Gross debt, excluding securitization debt (G-H)	2,318		2,060		1,797	1,804	1,793
Less cash and cash equivalents (I)	127		35		23	106	86
Net debt, excluding securitization debt (G-H-I)	2,191		2,026		1,775	1,698	1,707
Total capitalization (J)	4,243		3,858		3,472	3,448	3,321
Less securitization debt (K)	89		102		114	124	-
Total capitalization, excluding securitization debt (J-K)	4,154		3,756		3,358	3,324	3,321
Less cash and cash equivalents (L)	127		35		23	106	86
Net capitalization, excluding securitization debt (J-K-L)	4,027		3,722		3,335	3,218	3,235
(%)
Return on average invested capital – As-Reported (B/D)	5.3		5.5		6.2	6.7	3.7
Return on average invested capital – Operational ((B-C)/E)	5.5		6.0		6.4	6.8	3.7
Return on average common equity – As-Reported (A/F)	9.4		9.6		11.1	11.8	4.3
Return on average common equity – Operational ((A-C)/F)	9.6		10.5		11.1	11.8	4.3
Debt to capital ratio (G/J)	56.7		56.0		55.0	55.9	54.0
Debt to capital ratio, excluding securitization debt ((G-H)/(J-K))	55.8		54.8		53.5	54.3	54.0
Net debt to net capital ratio, excluding securitization debt ((G-H-I)/(J-K-L))	54.4		54.4		53.2	52.8	52.8
Calculations may differ due to rounding.

REG G RECONCILIATIONS
ENTERGY GULF STATES LOUISIANA FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011	2010	2009
As-Reported Earnings (A)	160.8		158.2		200.8	173.5	152.5
Preferred dividends	0.8		0.8		0.8	0.8	0.8
Tax-effected interest expense	48.2		49.2		49.7	60.2	70.7
As-Reported Earnings including preferred
dividends and tax-effected interest expense (B)	209.8		208.2		251.3	234.6	224.0
Special items
Transmission business spin-merge expenses	(2.8	)	(4.6	)	-	-	-
HCM implementation expenses	(2.5	)	-		-	-	-
Total special items (C)	(5.2	)	(4.6	)	-	-	-
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	215.0		212.8		251.3	234.6	224.0
Operational earnings (A-C)	166.0		162.8		200.8	173.5	152.5
Average invested capital (D)	2,944		2,888		2,962	3,122	3,344
Average invested capital, excluding assumption debt (E)	2,944		2,888		2,962	3,039	2,875
Average common equity (F)	1,412		1,348		1,389	1,429	1,348
Gross debt (G)	1,528		1,517		1,542	1,584	1,783
Less assumption debt (H)	-		-		-	-	168
Gross debt, excluding assumption debt (G-H)	1,528		1,517		1,542	1,584	1,615
Less cash and cash equivalents (I)	16		36		25	155	144
Net debt, excluding assumption debt (G-H-I)	1,512		1,482		1,517	1,429	1,471
Total capitalization (J)	2,988		2,900		2,876	3,049	3,196
Less assumption debt (K)	-		-		-	-	168
Total capitalization, excluding assumption debt (J-K)	2,988		2,900		2,876	3,049	3,028
Less cash and cash equivalents (L)	16		36		25	155	144
Net capitalization, excluding assumption debt (J-K-L)	2,972		2,865		2,851	2,893	2,884
(%)
Return on average invested capital – As-Reported (B/D)	7.1		7.2		8.5	7.5	6.7
Return on average invested capital – Operational ((B-C)/E)	7.3		7.4		8.5	7.7	7.8
Return on average common equity – As-Reported (A/F)	11.4		11.7		14.5	12.1	11.3
Return on average common equity – Operational ((A-C)/F)	11.8		12.1		14.5	12.1	11.3
Debt to capital ratio (G/J)	51.1		52.3		53.6	52.0	55.8
Debt to capital ratio, excluding assumption debt ((G-H)/(J-K))	51.1		52.3		53.6	52.0	53.3
Net debt to net capital ratio, excluding assumption debt ((G-H-I)/(J-K-L))	50.9		51.7		53.2	49.4	51.0
ENTERGY TEXAS – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011	2010	2009
As-Reported Net Income (A)	57.9		42.0		80.8	66.2	63.8
Preferred dividends	-		-		-	-	-
Tax-effected interest expense	54.7		57.2		56.0	56.5	63.9
As-Reported Net Income including preferred
dividends and tax-effected interest expense (B)	112.6		99.2		136.8	122.7	127.7
Special items
Transmission business spin-merge expenses	(3.2	)	(4.6	)	-	-	-
HCM implementation expenses	(5.6	)	-		-	-	-
Total special items (C)	(8.8	)	(4.6	)	-	-	-
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	121.4		103.8		136.8	122.7	127.7
Operational earnings (A-C)	66.7		46.6		80.8	66.2	63.8
Average invested capital (D)	2,458		2,524		2,530	2,493	2,374
Average invested capital, excluding securitization debt (E)	1,798		1,804		1,752	1,670	1,799
Average common equity (F)	871		877		862	834	872
Gross debt (G)	1,557		1,618		1,677	1,659	1,658
Less securitization debt (H)	629		690		750	807	838
Gross debt, excluding securitization debt (G-H)	928		928		927	852	820
Less cash and cash equivalents (I)	47		60		65	35	201
Net debt, excluding securitization debt (G-H-I)	881		867		862	817	619
Total capitalization (J)	2,444		2,472		2,576	2,484	2,503
Less securitization debt (K)	629		690		750	807	838
Total capitalization, excluding securitization debt (J-K)	1,815		1,782		1,827	1,676	1,664
Less cash and cash equivalents (L)	47		60		65	35	201
Net capitalization, excluding securitization debt (J-K-L)	1,768		1,722		1,762	1,641	1,463
(%)
Return on average invested capital – As-Reported (B/D)	4.6		3.9		5.4	4.9	5.4
Return on average invested capital – Operational ((B-C)/E)	6.8		5.5		7.8	7.3	7.1
Return on average common equity – As-Reported (A/F)	6.6		4.8		9.4	7.9	7.3
Return on average common equity – Operational ((A-C)/F)	7.7		5.3		9.4	7.9	7.3
Debt to capital ratio (G/J)	63.7		65.4		65.1	66.8	66.3
Debt to capital ratio, excluding securitization debt ((G-H)/(J-K))	51.1		52.2		50.8	50.8	49.3
Net debt to net capital ratio, excluding securitization debt ((G-H-I)/(J-K-L))	49.8		50.4		48.9	49.8	42.3
Calculations may differ due to rounding.

REG G RECONCILIATIONS
ENTERGY LOUISIANA FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011	2010	2009
As-Reported Earnings (A)	245.5		274.1		467.0	224.5	225.9
Preferred dividends	7.0		7.0		7.0	7.0	7.0
Tax-effected interest expense	86.4		72.9		61.2	62.5	52.7
As-Reported Earnings including preferred
dividends and tax-effected interest expense (B)	338.9		354.0		535.2	294.0	285.6
Special items
Transmission business spin-merge expenses	(1.2	)	(6.6	)	-	-	-
HCM implementation expenses	(2.6	)	-		-	-	-
Total special items (C)	(3.8	)	(6.6	)	-	-	-
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	342.7		360.6		535.2	294.0	285.6
Operational earnings (A-C)	249.3		280.7		467.0	224.5	225.9
Average invested capital (D)	6,075		5,406		4,414	3,890	3,491
Average invested capital, excluding securitization (E)	5,901		5,212		4,311	3,890	3,491
Average members’ equity (F)	2,923		2,718		2,251	1,924	1,710
Gross debt (G)	3,222		2,881		2,297	1,830	1,902
Less securitization debt (H)	165		182		207	-	-
Gross debt, excluding securitization debt (G-H)	3,058		2,699		2,090	1,830	1,902
Less cash and cash equivalents (I)	124		30		1	123	152
Net debt, excluding securitization debt (G-H-I)	2,934		2,669		2,089	1,707	1,750
Total capitalization (J)	6,198		5,951		4,862	3,967	3,813
Less securitization debt (K)	165		182		207	-	-
Total capitalization, excluding securitization debt (J-K)	6,033		5,770		4,655	3,967	3,813
Less cash and cash equivalents (L)	124		30		1	123	152
Net capitalization, excluding securitization debt (J-K-L)	5,909		5,740		4,654	3,844	3,662
(%)
Return on average invested capital – As-Reported (B/D)	5.6		6.5		12.1	7.6	8.2
Return on average invested capital – Operational ((B-C)/E)	5.8		6.9		12.4	7.6	8.2
Return on average members’ equity – As-Reported (A/F)	8.4		10.1		20.7	11.7	13.2
Return on average members’ equity – Operational ((A-C)/F)	8.5		10.3		20.7	11.7	13.2
Debt to capital ratio (G/J)	52.0		48.4		47.2	46.1	49.9
Debt to capital ratio, excluding securitization debt ((G-H)/(J-K))	50.7		46.8		44.9	46.1	49.9
Net debt to net capital ratio, excluding securitization debt ((G-H-I)/(J-K-L))	49.6		46.5		44.9	44.4	47.8
Calculations may differ due to rounding.

REG G RECONCILIATIONS
ENTERGY MISSISSIPPI FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011	2010	2009
As-Reported Earnings (A)	79.3		43.9		105.9	82.5	76.5
Preferred dividends	2.8		2.8		2.8	2.8	2.8
Tax-effected interest expense	35.4		34.0		29.5	32.1	30.5
As-Reported Earnings including preferred
dividends and tax-effected interest expense (B)	117.5		80.8		138.3	117.4	109.9
Special items
Transmission business spin-merge expenses	(0.9	)	(7.5	)	-	-	-
HCM implementation expenses	(4.5	)	-		-	-	-
Total special items (C)	(5.4	)	(7.5	)	-	-	-
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	122.9		88.3		138.3	117.4	109.9
Operational earnings (A-C)	84.7		51.4		105.9	82.5	76.5
Average invested capital (D)	2,084		1,963		1,720	1,609	1,509
Average common equity (E)	916		858		784	714	681
Gross debt (F)	1,059		1,178		931	839	852
Less cash and cash equivalents (G)	-		53		-	1	91
Net debt (F-G)	1,059		1,125		931	837	760
Total capitalization (H)	2,061		2,108		1,817	1,622	1,596
Less cash and cash equivalents (I)	-		53		-	1	91
Net capitalization (H-I)	2,061		2,055		1,817	1,621	1,505
(%)
Return on average invested capital – As-Reported (B/D)	5.6		4.1		8.0	7.3	7.3
Return on average invested capital – Operational ((B-C)/D)	5.9		4.5		8.0	7.3	7.3
Return on average common equity – As-Reported (A/E)	8.7		5.1		13.5	11.6	11.2
Return on average common equity – Operational ((A-C)/E)	9.3		6.0		13.5	11.6	11.2
Debt to capital ratio (F/H)	51.4		55.9		51.2	51.7	53.4
Net debt to net capital ratio ((F-G)/(H-I))	51.4		54.7		51.2	51.7	50.5
ENTERGY NEW ORLEANS FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011	2010	2009
As-Reported Earnings (A)	10.7		16.1		35.0	30.1	29.5
Preferred dividends	1.0		0.9		1.0	1.0	1.0
Tax-effected interest expense	8.1		6.8		6.7	7.9	10.4
As-Reported Earnings including preferred
dividends and tax-effected interest expense (B)	19.8		23.8		42.7	39.0	40.9
Special items
Transmission business spin-merge expenses	(0.1	)	(0.9	)	-	-	-
HCM implementation expenses	(2.7	)	-		-	-	-
Total special items (C)	(2.9	)	(0.9	)	-	-	-
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	22.5		24.7		42.7	39.0	40.9
Operational earnings (A-C)	13.6		17.0		35.0	30.1	29.5
Average invested capital (D)	432		390		371	436	499
Average common equity (E)	201		188		185	197	207
Gross debt (F)	226		196		167	167	272
Less cash and cash equivalents (G)	34		9		10	55	191
Net debt (F-G)	192		187		157	112	81
Total capitalization (H)	452		412		367	375	497
Less cash and cash equivalents (I)	34		9		10	55	191
Net capitalization (H-I)	418		402		358	320	306
(%)
Return on average invested capital – As-Reported (B/D)	4.6		6.1		11.5	8.9	8.2
Return on average invested capital – Operational ((B-C)/D)	5.2		6.3		11.5	8.9	8.2
Return on average common equity – As-Reported (A/E)	5.3		8.5		19.0	15.3	14.3
Return on average common equity – Operational ((A-C)/E)	6.8		9.0		19.0	15.3	14.3
Debt to capital ratio (F/H)	50.0		47.7		45.3	44.6	54.8
Net debt to net capital ratio ((F-G)/(H-I))	46.0		46.5		43.8	35.1	26.5
Calculations may differ due to rounding.

REG G RECONCILIATIONS
SYSTEM ENERGY RESOURCES FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011		2010		2009
As-Reported Net Income (A)	113.7		111.9		64.2		82.6		48.9
Preferred dividends	-		-		-		-		-
Tax-effected interest expense	23.0		23.4		25.5		29.9		26.7
As-Reported Net Income including preferred
dividends and tax-effected interest expense (B)	136.7		135.3		89.7		112.5		75.6
Special items
Transmission business spin-merge expenses	-		-		-		-		-
HCM implementation expenses	-		-		-		-		-
Total special items (C)	-		-		-		-		-
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	136.7		135.3		89.7		112.5		75.6
Operational earnings (A-C)	113.7		111.9		64.2		82.6		48.9
Average invested capital (D)	1,645		1,602		1,614		1,666		1,703
Average common equity (E)	854		817		806		821		843
Gross debt (F)	757		824		747		869		820
Less cash and cash equivalents (G)	127		84		185		264		264
Net debt (F-G)	630		740		562		605		556
Total capitalization (H)	1,634		1,657		1,548		1,681		1,650
Less cash and cash equivalents (I)	127		84		185		264		264
Net capitalization (H-I)	1,507		1,573		1,362		1,417		1,386
(%)
Return on average invested capital – As-Reported (B/D)	8.3		8.4		5.6		6.8		4.4
Return on average invested capital – Operational ((B-C)/D)	8.3		8.4		5.6		6.8		4.4
Return on average common equity – As-Reported (A/E)	13.3		13.7		8.0		10.1		5.8
Return on average common equity – Operational ((A-C)/E)	13.3		13.7		8.0		10.1		5.8
Debt to capital ratio (F/H)	46.4		49.7		48.3		51.7		49.7
Net debt to net capital ratio ((F-G)/(H-I))	41.8		47.1		41.2		42.7		40.1
ENTERGY WHOLESALE COMMODITIES FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012		2011		2010		2009
As-Reported Net Income (A)	42.9		40.4		488.6		447.4		606.7
Preferred dividends	0.1		-		3.3		2.7		2.6
Tax-effected interest expense	10.0		11.0		20.3		63.2		72.0
As-Reported Net Income including preferred
dividends and tax-effected interest expense (B)	53.0		51.4		512.2		513.3		681.3
Special items
VY asset impairments/related charges	(204.8	)	(223.5	)	-		-		-
HCM implementation expenses	(15.0	)	-		-		-		-
Non-utility nuclear spin-off expenses	-		-		-		(100.7	)	(44.0	)
Total special items (C)	(219.8	)	(223.5	)	-		(100.7	)	(44.0	)
Operational earnings including preferred
dividends and tax-effected interest expense (B-C)	272.8		274.9		512.2		614.0		725.3
Operational earnings (A-C)	262.7		263.9		488.6		548.1		650.7
Average invested capital (D)	5,145		5,513		5,627		5,378		4,956
Average common equity (E)	4,978		5,328		5,029		4,252		3,589
Gross debt (F)	199		111		204		851		1,228
Less cash and cash equivalents (G)	176		141		323		454		453
Net debt (F-G)	23		(30	)	(119	)	397		775
Total capitalization (H)	4,948		5,341		5,685		5,569		5,187
Less cash and cash equivalents (I)	176		141		323		454		453
Net capitalization (H-I)	4,772		5,201		5,362		5,115		4,734
(%)
Return on average invested capital – As-Reported (B/D)	1.0		0.9		9.1		9.5		13.7
Return on average invested capital – Operational ((B-C)/D)	5.3		5.0		9.1		11.4		14.6
Return on average common equity – As-Reported (A/E)	0.9		0.8		9.7		10.5		16.9
Return on average common equity – Operational ((A-C)/E)	5.3		5.0		9.7		12.9		18.1
Debt to capital ratio (F/H)	4.0		2.1		3.6		15.3		23.7
Net debt to net capital ratio ((F-G)/(H-I))	0.5		(0.6	)	(2.2	)	7.8		16.4
Certain prior year data has been reclassified to conform with current year presentation.
Calculations may differ due to rounding.

REG G RECONCILIATIONS
ENTERGY WHOLESALE COMMODITIES FINANCIAL MEASURES – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
1Q12-4Q13
($ millions)	1Q13		2Q13		3Q13		4Q13		1Q12		2Q12		3Q12		4Q12
For the quarter:
As-Reported Net Income (A)	82.1		11.5		(92.8	)	42.1		(175.9	)	70.8		86.8		58.8
Less special items (B)	-		(1.1	)	(175.2	)	(43.6	)	(223.5	)	-		-		-
Operational earnings (A-B)	82.1		12.7		82.3		85.6		47.5		70.8		86.8		58.8
As-Reported Net Income, rolling 12 months (C)	298.5		239.3		59.7		42.9		198.9		171.4		136.6		40.4
Preferred dividends	-		-		-		0.9		2.6		1.9		1.2		-
Tax-effected interest expense	9.1		8.0		8.7		10.0		18.6		16.7		12.7		11.0
As-Reported Net Income, rolling
12 months including preferred
dividends and tax-effected interest
expense (D)	307.6		247.3		68.4		53.8		220.1		190.0		150.6		51.4
Special items in prior quarters	-		-		(1.1	)	(176.3	)	-		(223.5	)	(223.5	)	(223.5	)
Special items in current quarter	-		(1.1	)	(175.2	)	(43.6	)	(223.5	)	-		-		-
Total special items (E)	-		(1.1	)	(176.3	)	(219.8	)	(223.5	)	(223.5	)	(223.5	)	(223.5	)
Operational earnings, rolling 12 months including
preferred dividends and tax-effected interest
expense (D-E)	307.6		248.4		244.7		273.6		443.6		413.4		374.0		274.9
Operational earnings, rolling 12 months (C-E)	298.5		240.4		236.0		262.7		422.4		394.9		360.1		263.9
Average invested capital (F)	5,548		5,539		5,456		5,145		5,626		5,603		5,552		5,513
Average common equity (G)	5,390		5,415		5,235		4,978		5,155		5,167		5,136		5,328
Gross debt (H)	110		111		316		199		207		137		127		111
Less cash and cash equivalents (I)	162		140		126		177		260		106		192		141
Net debt (H-I)	(52	)	(29	)	191		22		(53	)	31		(65	)	(30	)
Total capitalization (J)	5,439		5,578		5,536		4,948		5,657		5,499		5,377		5,341
Less cash and cash equivalents (K)	162		140		126		177		260		106		192		141
Net capital (J-K)	5,277		5,438		5,410		4,771		5,397		5,393		5,184		5,201
(%)
Return on average invested capital –
As-Reported (D/F)	5.5		4.5		1.3		1.0		3.9		3.4		2.7		0.9
Return on average invested capital –
Operational ((D-E)/F)	5.5		4.5		4.5		5.3		7.9		7.4		6.7		5.0
Return on average common equity –
As-Reported (C/G)	5.5		4.4		1.1		0.9		3.9		3.3		2.7		0.8
Return on average common equity –
Operational ((C-E)/G)	5.5		4.4		4.5		5.3		8.2		7.6		7.0		5.0
Debt to capital ratio (H/J)	2.0		2.0		5.7		4.0		3.7		2.5		2.4		2.1
Net debt to net capital ratio ((H-I)/(J-K))	(1.0	)	(0.5	)	3.5		0.5		(1.0	)	0.6		(1.2	)	(0.6	)
Certain prior year data has been reclassified to conform with current year presentation.
Calculations may differ due to rounding.

REG G RECONCILIATIONS
ENTERGY WHOLESALE COMMODITIES OPERATIONAL ADJUSTED EBITDA – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
1Q12-4Q13
($ millions)	1Q13	2Q13		3Q13		4Q13		1Q12		2Q12		3Q12	4Q12
Net Income	82	12		(93	)	42		(176	)	71		87	59
Add back: interest expense	3	4		4		5		6		5		3	3
Add back: income tax expense	57	(15	)	(107	)	(12	)	(92	)	47		57	50
Add back: depreciation and amortization	49	50		55		61		51		48		29	47
Subtract: interest and investment income	28	22		21		66		31		27		20	28
Add back: decommissioning expense	31	30		32		33		30		(17	)	29	30
Subtract: other than temporary impairments	-	-		-		-		-		-		-	-
Adjusted EBITDA	194	59		(130	)	63		(212	)	127		185	161
Add back: special item for HCM	-	2		3		19		-		-		-	-
implementation expenses (pre-tax)
Add back: VY asset impairments	-	-		292		52		356		-		-	-
/related charges (pre-tax)
Operational adjusted EBITDA	194	61		165		133		144		127		185	161
Certain prior year data has been reclassified to conform with current year presentation.

ENTERGY WHOLESALE COMMODITIES OPERATIONAL ADJUSTED EBITDA – RECONCILIATION OF GAAP TO NON-GAAP MEASURES
2009-2013
($ millions)	2013		2012	2011	2010		2009
Net Income	43		40	492	450		609
Add back: interest expense	16		18	33	103		117
Add back: income tax expense	(77	)	61	176	248		287
Add back: depreciation and amortization	216		176	179	163		152
Subtract: interest and investment income	138		105	99	142		168
Add back: decommissioning expense	125		72	81	107		99
Subtract: other than temporary impairments	-		-	-	(1	)	(86	)
Adjusted EBITDA	185		262	862	931		1,182
Add back: special item for HCM	24		-	-	-		-
implementation expenses (pre-tax)
Add back: VY asset impairments	343		356	-	-		-
/related charges (pre-tax)
Add back: Non-utility nuclear spin-off	-		-	-	117		48
expenses (pre-tax)
Operational adjusted EBITDA	553		618	862	1,048		1,230
Certain prior year data has been reclassified to conform with current year presentation.
Totals may not foot due to rounding.

ENTERGY CORPORATION AND SUBSIDIARIES
INVESTOR NEWS	ENTERGY COMMON STOCK PRICES
Entergy’s quarterly earnings results, webcasts, presentations, and other	The high and low trading prices for each quarterly period in 2013 and 2012
news and information of investor interest may be obtained by visiting the	were as follows (in dollars):
investor information page on Entergy’s corporate website at entergy.com			2013		2012
or calling Entergy's Investor Relations information line at	QUARTER		HIGH	LOW	HIGH	LOW
1-888-ENTERGY (368-3749).	1		65.39	61.09	73.66	66.23
	2		72.10	63.12	68.20	62.97
INVESTOR RELATIONS	3		72.60	61.66	74.50	67.07
Security analysts, portfolio managers, and other members of the financial	4		68.63	60.22	72.98	61.55
community may contact:
Paula Waters	DIVIDEND PAYMENTS
Vice President, Investor Relations	The Board of Directors declares dividends quarterly and sets the record and
Telephone: 504-576-4380	payment dates. Subject to Board discretion, those dates for 2014 are:
E–mail: pwater1@entergy.com
	DECLARATION DATE			RECORD DATE		PAYMENT DATE
SHAREHOLDER ACCOUNT INFORMATION	January 31			February 13		March 3
Wells Fargo Shareowner Services is Entergy’s transfer agent,	April 17			May 15		June 2
registrar, dividend disbursing agent, and dividend reinvestment	July 25			August 14		September 2
and stock purchase plan agent. Shareholders of record with	October 31			November 13		December 1
questions about lost certificates, lost or missing dividend checks
or notifications of change of address should contact:	Quarterly dividend payments (in cents-per-share):
Wells Fargo Shareowner Services
P.O. Box 64874	QUARTER	2014	2013	2012	2011	2010
St. Paul, MN 55164-0874	1	83	83	83	83	75
Phone: 1-855-854-1360	2	83	83	83	83	83
Internet: www.shareowneronline.com	3		83	83	83	83
	4		83	83	83	83
CORPORATE GOVERNANCE
Entergy’s Corporate Governance Guidelines, Board Committee Charters	PREFERRED STOCK DIVIDEND PAYMENTS
for the Corporate Governance, Audit, and Personnel Committees, and	The board of directors for each preferred stock issuer declares preferred
Entergy’s Code of Conduct may be accessed electronically by selecting	dividends quarterly and sets the record and payment dates. Subject to
the investor information page on Entergy’s corporate website at	their discretion, those dates for 2014 and 2015 are:
entergy.com.
ADDITIONAL INFORMATION	UTILITY OPERATING COMPANY			RECORD DATE		PAYMENT DATE
For copies of the above Corporate Governance documents, Entergy’s	Entergy Arkansas, Inc.			12/23/13		1/2/14
10-K and 10-Q reports filed with the Securities and Exchange				3/20/14		4/1/14
Commission, or for other investor information, call 1-888-ENTERGY				6/20/14		7/1/14
or write to:				9/22/14		10/1/14
Entergy Corporation				12/22/14		1/2/15
Investor Relations				3/20/15		4/1/15
P.O. Box 61000				6/22/15		7/1/15
New Orleans, LA 70161				9/21/15		10/1/15
	Entergy Gulf States Louisiana, L.L.C.			2/27/14		3/17/14
COMMON STOCK INFORMATION				5/30/14		6/16/14
The company’s common stock is listed on the New York and Chicago				8/29/14		9/15/14
exchanges under the symbol “ETR” (CUSIP 29364G10). The Entergy				11/28/14		12/15/14
share price is reported daily in the financial press under “Entergy” in				2/27/15		3/16/15
most listings of New York Stock Exchange securities. Entergy common				5/29/15		6/15/15
stock is a component of the following indices: S&P 500, S&P Utilities				8/28/15		9/15/15
Index, Philadelphia Utility Index and the NYSE Composite Index,				11/27/15		12/15/15
among others.	Entergy Louisiana, LLC			2/27/14		3/17/14
				5/30/14		6/16/14
As of January 31, 2014, there were 178,563,836 shares of Entergy				8/29/14		9/15/14
common stock outstanding. Shareholders of record totaled				11/28/14		12/15/14
32,163, and approximately 116,000 investors held Entergy stock in				2/27/15		3/16/15
“street name” through a broker.				5/29/15		6/15/15
				8/28/15		9/15/15
CERTIFICATIONS				11/27/15		12/15/15
In May 2013, Entergy’s Chief Executive Officer certified to the	Entergy Mississippi, Inc.			1/25/14		2/3/14
New York Stock Exchange that he was not aware of any violation				4/21/14		5/1/14
of the NYSE corporate governance listing standards. Also, Entergy				7/21/14		8/1/14
filed certifications regarding the quality of the company’s public				10/20/14		11/3/14
disclosure, required by Section 302 of the Sarbanes-Oxley Act of				1/20/15		2/2/15
2002, as exhibits to its Report on Form 10-K for the fiscal year ended				4/20/15		5/1/15
December 31, 2013.				7/20/15		8/3/15
				10/20/15		11/2/15
	Entergy New Orleans, Inc.			12/23/13		1/2/14
				3/20/14		4/1/14
				6/20/14		7/1/14
				9/22/14		10/1/14
				12/22/14		1/2/15
				3/20/15		4/1/15
				6/22/15		7/1/15
				9/21/15		10/1/15