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•	resolution of pending and future rate cases and negotiations, including various performance-based rate discussions, Entergy’s utility supply plan, and recovery of fuel and purchased power costs;

•

the termination of Entergy Arkansas’s participation in the System Agreement, which occurred in December 2013, the termination of Entergy Mississippi’s participation in the System Agreement in November 2015, the termination of Entergy Texas’s, Entergy Gulf States Louisiana’s, and Entergy Louisiana’s participation in the System Agreement after expiration of the proposed 60-month notice period or such other period as approved by the FERC;

•

regulatory and operating challenges and uncertainties and economic risks associated with the Utility operating companies’ move to MISO, which occurred in December 2013, including the effect of current or projected MISO market rules and system conditions in the MISO markets, the allocation of MISO system transmission upgrade costs, and the effect of planning decisions that MISO makes with respect to future transmission investments by the Utility operating companies;

•	changes in utility regulation, including the beginning or end of retail and wholesale competition, the ability to recover net utility assets and other potential stranded costs, and the application of more stringent transmission reliability requirements or market power criteria by the FERC;

•	changes in the regulation or regulatory oversight of Entergy’s nuclear generating facilities and nuclear materials and fuel, including with respect to the planned or potential shutdown of nuclear generating facilities owned or operated by Entergy Wholesale Commodities, and the effects of new or existing safety or environmental concerns regarding nuclear power plants and nuclear fuel;

•	resolution of pending or future applications, and related regulatory proceedings and litigation, for license renewals or modifications or other authorizations required of nuclear generating facilities;

•	the performance of and deliverability of power from Entergy’s generation resources, including the capacity factors at its nuclear generating facilities;

•	Entergy’s ability to develop and execute on a point of view regarding future prices of electricity, natural gas, and other energy-related commodities;

•	prices for power generated by Entergy’s merchant generating facilities and the ability to hedge, meet credit support requirements for hedges, sell power forward or otherwise reduce the market price risk associated with those facilities, including the Entergy Wholesale Commodities nuclear plants;

•	the prices and availability of fuel and power Entergy must purchase for its Utility customers, and Entergy’s ability to meet credit support requirements for fuel and power supply contracts;

•	volatility and changes in markets for electricity, natural gas, uranium, emissions allowances, and other energy-related commodities, and the effect of those changes on Entergy and its customers;

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•	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 dioxide, nitrogen oxide, greenhouse gases, mercury, and other regulated air and water emissions, and changes in costs of compliance with environmental and other laws and regulations;

•	uncertainty regarding the establishment of interim or permanent sites for spent nuclear fuel and nuclear waste storage and disposal and the level of spent fuel disposal fees charged by the U.S. government related to such sites;

•	variations in weather and the occurrence of hurricanes and other storms and disasters, including uncertainties associated with efforts to remediate the effects of hurricanes, ice storms, or other weather events and the recovery of costs associated with restoration, including accessing funded storm reserves, federal and local cost recovery mechanisms, securitization, and insurance;

•	effects of climate change;

•	changes in the quality and availability of water supplies and the related regulation of water use and diversion;

•	Entergy’s ability to manage its capital projects and operation and maintenance costs;

•	Entergy’s ability to purchase and sell assets at attractive prices and on other attractive terms;

•	the economic climate, and particularly economic conditions in Entergy’s Utility service area and the Northeast United States and events and circumstances that could influence economic conditions in those areas, and the risk that anticipated load growth may not materialize;

•	the effects of Entergy’s strategies to reduce tax payments;

•	changes in the financial markets, particularly those affecting the availability of capital and Entergy’s ability to refinance existing debt, execute share repurchase programs, and fund investments and acquisitions;

•	actions of rating agencies, including changes in the ratings of debt and preferred stock, changes in general corporate ratings, and changes in the rating agencies’ ratings criteria;

•	changes in inflation and interest rates;

•	the effect of litigation and government investigations or proceedings;

•	changes in technology, including with respect to new, developing, or alternative sources of generation;

•	the potential effects of threatened or actual terrorism, cyber attacks or data security breaches, including increased security costs, and war or a catastrophic event such as a nuclear accident or a natural gas pipeline explosion;

•	Entergy’s ability to attract and retain talented management and directors;

•	changes in accounting standards and corporate governance;

•	declines in the market prices of marketable securities and resulting funding requirements for Entergy’s defined benefit pension and other postretirement benefit plans;

•	future wage and employee benefit costs, including changes in discount rates and returns on benefit plan assets;

•	changes in decommissioning trust fund values or earnings or in the timing of or cost to decommission nuclear plant sites;

•	the implementation of the shutdown of Vermont Yankee and the related decommissioning of Vermont Yankee;

•	the effectiveness of Entergy’s risk management policies and procedures and the ability and willingness of its counterparties to satisfy their financial and performance commitments;

•	factors that could lead to impairment of long-lived assets; and

•	the ability to successfully complete merger, acquisition, or divestiture plans, regulatory or other limitations imposed as a result of merger, acquisition, or divestiture, and the success of the business following a merger, acquisition, or divestiture.

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•	The Utility business segment includes the generation, transmission, distribution, and sale of electric power in portions of Arkansas, Mississippi, Texas, and Louisiana, including the City of New Orleans; and operation of a small natural gas distribution business.

•

The Entergy Wholesale Commodities business segment includes the ownership, operation, and decommissioning of nuclear power plants located in the northern United States and the sale of the electric power produced by its operating plants to wholesale customers.  Entergy Wholesale Commodities also provides services to other nuclear power plant owners and owns interests in non-nuclear power plants that sell the electric power produced by those plants to wholesale customers.

(a)	Parent & Other includes eliminations, which are primarily intersegment activity.

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•	formula rate plan increases at Entergy Gulf States Louisiana and Entergy Louisiana, as approved by the LPSC, effective December 2014 and January 2015;

•	an annual net rate increase at Entergy Mississippi of $16 million, effective February 2015, as a result of the MPSC order in the June 2014 rate case;

•

an increase in energy efficiency rider revenue primarily due to an increase in the energy efficiency rider at Entergy Arkansas, as approved by the APSC, effective July 2014 and new energy efficiency riders at Entergy Gulf States Louisiana, Entergy Louisiana, and Entergy Mississippi that began in the fourth quarter 2014. Energy efficiency revenues are largely offset by costs included in other operation and maintenance expenses and have a minimal effect on net income; and

•	an annual base rate increase of $18.5 million at Entergy Texas, effective April 2014, as a result of the PUCT’s order in the September 2013 rate case.

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•	a decrease in net revenue as a result of Vermont Yankee ceasing power production in December 2014;

•	lower realized wholesale energy prices; and

•

in the fourth quarter 2014, Entergy Wholesale Commodities entered into electricity derivative instruments that were not designated as hedges, including additional financial power sales to lock in margins on some in-the-money purchased call options. When these positions settled, the turnaround of the positive year-end 2014 mark contributed to the negative mark-to-market variance for first quarter 2015. In the fourth quarter 2013, Entergy Wholesale Commodities also entered into similar transactions. The effect of increases in forward prices resulted in negative mark-to-market activity in fourth quarter 2013. The turnaround of the negative 2013 mark resulted in a positive mark in first quarter 2014, which also contributed to the negative mark-to-market variance for first quarter 2015. See Note 16 to the financial statements in the Form 10-K and Note 8 to the financial statements herein for discussion of derivative instruments.

(a)	The reduction in owned capacity is due to the retirement of the 605 MW Vermont Yankee plant in December 2014.

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•	an increase of $20 million in fossil-fueled generation expenses primarily due to an increase in scope of work done during plant outages;

•	an increase of $14 million in energy efficiency costs.  These costs are recovered through energy efficiency riders and have a minimal effect on net income;

•	an increase of $12 million in nuclear generation expenses primarily due to increased costs related to an NRC inspection in first quarter 2015, higher labor costs, including contract labor, higher materials costs, and higher NRC fees;

•	an increase of $7 million in transmission expenses primarily due to an increase in costs related to the participation in the MISO RTO. The net income effect is partially offset due to deferrals of some of these costs in certain jurisdictions.  See Note 2 to the financial statements in the Form 10-K for further information on the deferrals; and

•	an increase of $5 million primarily due to losses of $1 million on the sale of surplus diesel inventory in 2015 compared to gains of $4 million on the sale of surplus oil inventory in 2014.

•

a decrease of $8 million in compensation and benefits costs primarily due to a decrease in the accrual for incentive-based compensation, partially offset by an increase in net periodic pension and other postretirement benefit costs as a result of lower discount rates and changes in retirement and mortality assumptions.  See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for further discussion of benefits costs; and

•	a decrease of $5 million due to the timing of annual Nuclear Electric Insurance Limited distributions in 2015 as compared to 2014.

•	an increase in earnings on decommissioning trust fund investments in the first quarter 2015 as compared to the first quarter 2014. There is no effect on net income as the trust fund earnings are offset by a corresponding amount of regulatory charges; and

•	an increase in distributions earned on preferred membership interests purchased from Entergy Holdings Company with the proceeds received in August 2014 from the Act 55 storm cost financing. The distributions

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(a)	Calculation excludes the Arkansas, Louisiana, and Texas securitization bonds, which are non-recourse to Entergy Arkansas, Entergy Louisiana, and Entergy Texas, respectively.

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•	lower Entergy Wholesale Commodities net revenues in 2015 as compared to the same period in 2014, as discussed previously;

•	an increase in income tax payments of $62 million primarily due to payments made in 2015 for the final settlement of amounts outstanding associated with the 2006-2007 IRS audit;

•	an increase in spending of $49 million in 2015 related to Vermont Yankee, including severance and retention payments accrued in 2014 and defueling activities that took place after the plant ceased power production in December 2014; and

•	an increase of $20 million in pension contributions in 2015. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates – Qualified Pension and Other Postretirement Benefits” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

•	higher Utility net revenues in 2015 as compared to the same period in 2014, as discussed above;

•	a decrease of $16 million in spending on nuclear refueling outages in 2015 as compared to the same period in 2014; and

•	a decrease of $15 million in storm restoration spending in 2015.

•	an increase in construction expenditures primarily due to compliance with NRC post-Fukushima requirements, an overall higher scope of work on various projects, and a higher scope of work during plant outages in 2015 as compared to the same period in 2014, partially offset by a decrease in spending on the Ninemile Unit 6 self-build project and a decrease in storm restoration spending;

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•	a change in collateral deposit activity, reflected in the “Decrease in other investments” line on the Consolidated Statement of Cash Flows, as Entergy received net deposits of $21 million in 2014.  Entergy Wholesale Commodities’ forward sales contracts are discussed in the “Market and Credit Risk Sensitive Instruments” section below;

•

a decrease of $15 million in insurance proceeds primarily due to $13 million received in the first quarter 2015 related to the Baxter Wilson plant event and $24 million received in the first quarter 2014 for property damages related to the generator stator incident at ANO. See Note 1 to the financial statements herein and Note 8 to the financial statements in the Form 10-K for a discussion of the Baxter Wilson plant event and the ANO stator incident; and

•	proceeds from the sale of aircraft in first quarter 2014.

•	long-term debt activity using approximately $197 million of cash in 2015 compared to providing $17 million of cash in 2014.  Included in the long-term debt activity is $187 million in 2015 and $140 million in 2014 for the repayment of borrowings on the Entergy Corporation long-term credit facility;

•	net issuances of commercial paper of $278 million in 2015 compared to net issuances of commercial paper of $14 million in 2014;

•	the repurchase of $25 million of Entergy common stock in 2015; and

•	a net decrease of $212 million in 2015 in short-term borrowings by the nuclear fuel company variable interest entities.

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(a)	Percent of planned generation output sold or purchased forward under contracts, forward physical contracts, forward financial contracts, or options that mitigate price uncertainty that may require regulatory approval or approval of transmission rights. Positions that are not classified as hedges are netted in the planned generation under contract.

(b)	Transaction under which power is supplied from a specific generation asset; if the asset is not operating, seller is generally not liable to buyer for any damages.

(c)

A sale of power on a unit-contingent basis coupled with a guarantee of availability provides for the payment to the power purchaser of contract damages, if incurred, in the event the seller fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold.  All of Entergy’s outstanding guarantees of availability provide for dollar limits on Entergy’s maximum liability under such guarantees.

(d)

Transaction that requires receipt or delivery of energy at a specified delivery point (usually at a market hub not associated with a specific asset) or settles financially on notional quantities; if a party fails to deliver or receive energy, defaulting party must compensate the other party as specified in the contract, a portion of which may be capped through the use of risk management products. This also includes option transactions that may expire without being exercised.

(e)	Transactions for the purchase of energy, generally to offset a Firm LD transaction.

(f)	Amount of output expected to be generated by Entergy Wholesale Commodities resources considering plant operating characteristics, outage schedules, and expected market conditions that affect dispatch.

(g)

Assumes NRC license renewals for plants whose current licenses expire within five years, and uninterrupted normal operation at all operating plants.  NRC license renewal applications are in process for two units, as follows (with current license expirations in parentheses): Indian Point 2 (September 2013 and now operating under its period of extended operations while its application is pending) and Indian Point 3 (December 2015).  For a discussion regarding the license renewals for Indian Point 2 and Indian Point 3, see “Entergy Wholesale Commodities Authorizations to Operate Its Nuclear Power Plants” above and in the Form10-K.

(h)	Percent of planned qualified capacity sold to mitigate price uncertainty under physical or financial transactions.

(i)	A contract for the sale of installed capacity and related energy, priced per megawatt-hour sold.

(j)	A contract for the sale of an installed capacity product in a regional market.

(k)

Contracts priced in accordance with cost-based rates, a ratemaking concept used for the design and development of rate schedules to ensure that the filed rate schedules recover only the cost of providing the service; these contracts are on owned non-utility resources located within Entergy’s Utility service area and were executed prior to receiving market-based rate authority under MISO.  The percentage sold assumes completion of the necessary transmission upgrades required for the approved transmission rights.

(l)	Non-nuclear planned generation and net MW in operation include purchases from affiliated and non-affiliated counterparties under long-term contracts and exclude energy and capacity from Entergy Wholesale Commodities’ wind investment. The decrease in planned net MW in operation beginning in 2017 is due to the expiration of a non-affiliated 75 MW contract.

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(a)	These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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(a)	These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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(a)	These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

(a)	These accumulated other comprehensive income (loss) components are included in the computation of net periodic pension and other postretirement cost.  See Note 6 to the financial statements herein for additional details.

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(a)	The interest rate is the rate as of March 31, 2015 that would most likely apply to outstanding borrowings under the facility.

(b)	Borrowings under the Entergy Arkansas credit facility may be secured by a security interest in its accounts receivable at Entergy Arkansas’s option. In April 2015, Entergy Arkansas renewed its credit facility through April 2016.

(c)	The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility.  As of March 31, 2015, no letters of credit were outstanding.

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(d)	The credit facility allows Entergy Gulf States Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility.  As of March 31, 2015, no letters of credit were outstanding.

(e)	The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility.  As of March 31, 2015, no letters of credit were outstanding.

(f)	Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option. Prior to expiration on May 31, 2015, Entergy Mississippi expects to renew all of its credit facilities.

(g)	The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.  As of March 31, 2015, $1.3 million in letters of credit were outstanding.

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(a)	Includes letter of credit fees and bank fronting fees on commercial paper issuances by the nuclear fuel company variable interest entities for Entergy Arkansas, Entergy Louisiana, and System Energy.  The nuclear fuel company variable interest entity for Entergy Gulf States Louisiana does not issue commercial paper, but borrows directly on its bank credit facility.

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(a)	In April 2015, the System Energy nuclear fuel company variable interest entity redeemed, at maturity, its $60 million of 5.33% Series G Notes.

(a)	The values exclude lease obligations of $112 million at Entergy Louisiana and $39 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $80 million at Entergy, and include debt due within one year.

(b)	Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements and are based on prices derived from inputs such as benchmark yields and reported trades.

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(a)	The values exclude lease obligations of $128 million at Entergy Louisiana and $51 million at System Energy, long-term DOE obligations of $181 million at Entergy Arkansas, and the note payable to NYPA of $80 million at Entergy, and include debt due within one year.

(b)	Fair values are classified as Level 2 in the fair value hierarchy discussed in Note 8 to the financial statements and are based on prices derived from inputs such as benchmark yields and reported trades.

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(a)	Represents the gross amounts of recognized assets/liabilities

(b)	Represents the netting of fair value balances with the same counterparty

(c)	Represents the net amounts of assets /liabilities presented on the Entergy Consolidated Balance Sheets

(d)	Excludes cash collateral in the amounts of $1 million posted as of March 31, 2015 and $25 million held as of December 31, 2014, respectively

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(a)	Due to regulatory treatment, the natural gas swaps are marked-to-market through fuel, fuel-related expenses, and gas purchased for resale and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as fuel expenses when the swaps are settled are recovered or refunded through fuel cost recovery mechanisms.

(b)

Due to regulatory treatment, the changes in the estimated fair value of FTRs for the Utility operating companies are recorded through purchased power expense and then such amounts are simultaneously reversed and recorded as an offsetting regulatory asset or liability.  The gains or losses recorded as purchased power expense when the FTRs for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

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(a)	No cash collateral was required to be posted as of March 31, 2015 and December 31, 2014, respectively.

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•

Level 1 - Level 1 inputs are unadjusted quoted prices in active markets for identical assets or liabilities that the entity has the ability to access at the measurement date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.  Level 1 primarily consists of individually owned common stocks, cash equivalents (temporary cash investments, securitization recovery trust account, and escrow accounts), debt instruments, and gas hedge contracts.  Cash equivalents includes all unrestricted highly liquid debt instruments with an original maturity of three months or less at the date of purchase.

•

Level 2 - Level 2 inputs are inputs other than quoted prices included in Level 1 that are, either directly or indirectly, observable for the asset or liability at the measurement date.  Assets are valued based on prices derived by independent third parties that use inputs such as benchmark yields, reported trades, broker/dealer quotes, and issuer spreads.  Prices are reviewed and can be challenged with the independent parties and/or overridden by Entergy if it is believed such would be more reflective of fair value.  Level 2 inputs include the following:

-	inputs that are derived principally from or corroborated by observable market data by correlation or other means.

•	Level 3 - Level 3 inputs are pricing inputs that are generally less observable or unobservable from objective sources.  These inputs are used with internally developed methodologies to produce management’s best estimate of fair value for the asset or liability.  Level 3 consists primarily of FTRs and derivative power contracts used as cash flow hedges of power sales at merchant power plants.

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(a)	The decommissioning trust funds hold equity and fixed income securities. Equity securities are held to approximate the returns of major market indices.  Fixed income investments are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)	Commingled equity funds may be redeemed bi-monthly.

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(a)	The decommissioning trust funds hold equity and fixed income securities. Equity securities are held to approximate the returns of major market indices.  Fixed income investments are held in various governmental and corporate securities.  See Note 9 to the financial statements herein for additional information on the investment portfolios.

(b)	Commingled equity funds may be redeemed bi-monthly.

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•	an increase of $10.3 million in energy efficiency costs, including the effects of true-ups to the energy efficiency filings. Energy efficiency costs are recovered through the energy efficiency rider and have a minimal effect on net income;

•	an increase of $5.2 million in fossil-fueled generation expenses due to an overall higher scope of work done during plant outages as compared to the prior year; and

•	an increase of $3.1 million in nuclear generation expenses primarily due to higher contract labor costs.

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•	an increase of $18.9 million in spending on nuclear refueling outages in 2015 as compared to the same period in 2014;

•	an increase of $16 million in income tax payments. Entergy Arkansas made income tax payments of $17.6 million in 2015 in accordance with the Entergy Corporation and Subsidiary Companies Intercompany Income Tax Allocation Agreement. The income tax payments made in 2015 resulted primarily from final settlement of amounts outstanding associated with the 2006-2007 IRS audit;

•	$8.8 million in insurance proceeds received in the first quarter 2014 for property damages related to the generator stator incident at ANO. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - ANO Damage, Outage, and NRC Reviews” in the Form 10-K for a discussion of the ANO stator incident; and

•	an increase of $5.4 million in pension contributions in 2015. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Critical Accounting Estimates” in the Form 10-K and Note 6 to the financial statements herein for a discussion of qualified pension and other postretirement benefits funding.

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an increase in the recovery of fuel and purchased power costs including System Agreement bandwidth remedy collections from customers of $13.2 million received in the first quarter 2015 as a result of the compliance filing pursuant to the FERC’s February 2014 orders related to the bandwidth payments/receipts for the June - December 2005 period. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the System Agreement proceedings; and

•	a decrease of $4.2 million in interest paid in 2015 as compared to the same period in the prior year.

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•	fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle;

•	a decrease in distribution construction expenditures primarily due to storm restoration spending in 2014; and

•	money pool activity.

•	an increase in nuclear construction expenditures due to compliance with NRC post-Fukushima requirements and a higher scope of work on various nuclear projects in 2015; and

•	$24.2 million in insurance proceeds received in the first quarter 2014 for property damages related to the generator stator incident at ANO. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - ANO Damage, Outage, and NRC Reviews” in the Form 10-K for a discussion of the ANO stator incident .

•	the issuance of $375 million of 3.7% Series first mortgage bonds in March 2014;

•	net repayments of $28.5 million on the Entergy Arkansas nuclear fuel company variable interest entity credit facility in the first quarter 2015 compared to net borrowings of $62.5 million in the first quarter 2014; and

•	the repayment, prior to maturity, of a $250 million term loan in March 2014.

(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Arkansas.

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•	an increase of $2.1 million in nuclear generation expenses primarily due to higher labor costs, including contract labor, higher materials costs, and higher NRC fees;

•	an increase of $1.5 million as a result of spending related to the Entergy Louisiana and Entergy Gulf States Louisiana business combination. See “Entergy Louisiana and Entergy Gulf States Louisiana Business Combination” above for discussion of the business combination; and

•	an increase of $1.2 million in transmission expenses primarily due to an increase in costs related to the participation in the MISO RTO. The net income effect is partially offset due to deferrals of some of these costs.  See Note 2 to the financial statements in the Form 10-K for further information on the deferrals.

•	higher realized gains and higher earnings in 2015 on the River Bend decommissioning trust fund investments. There is no effect on net income as these investment gains are offset by a corresponding amount of regulatory charges;

•	an increase of $1.8 million as a result of income collected from contracts with independent power producers; and

•	an increase of $1.2 million due to distributions earned on preferred membership interests purchased from Entergy Holdings Company with the proceeds received in August 2014 from the Act 55 storm cost financing. See Note 2 to the financial statements in the Form 10-K for a discussion of the Act 55 storm cost financing.

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•	fluctuations in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle;

•	an increase in nuclear construction expenditures at the River Bend plant as a result of an increased scope of work performed in 2015; and

•	money pool activity.

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•	an increase of $5.8 million in fossil-fueled generation expenses primarily due to an overall higher scope of work done during plant outages as compared to prior year;

•	an increase resulting from losses of $1.2 million on the sale of surplus diesel inventory in 2015 compared to gains of $3.8 million on the sale of surplus oil inventory in 2014; and

•	an increase of $4.9 million in nuclear generation expenses primarily due to increased costs related to an NRC inspection in first quarter 2015.

•	the issuance of $250 million of 4.95% Series first mortgage bonds in November 2014;

•	the issuance of $190 million of 3.78% Series first mortgage bonds in July 2014; and

•	the decrease in the allowance for borrowed funds used during construction due to a higher construction work in progress balance in 2014, including the Ninemile Unit 6 project which was placed in service in December 2014.

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•	a decrease in nuclear fuel activity because of variations from year to year in the timing and pricing of fuel reload requirements in the Utility business, material and services deliveries, and the timing of cash payments during the nuclear fuel cycle; and

•	a decrease in fossil-fueled generation construction expenditures primarily due to a decrease in spending on the Ninemile Unit 6 project.

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(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Louisiana.

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•	increased recovery of fuel costs compared to prior year;

•	$15.1 million in insurance proceeds received in the first quarter 2015 related to the Baxter Wilson plant event. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Baxter Wilson Plant Event” in the Form 10-K for a discussion of the Baxter Wilson plant event; and

•	timing of collections from customers.

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•	$12.7 million of insurance proceeds received in the first quarter 2015 related to the Baxter Wilson Plant Event. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Baxter Wilson Plant Event” in the Form 10-K for a discussion of the Baxter Wilson plant event; and

•	money pool activity.

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•	an increase of $3.4 million in fossil-fueled generation expenses resulting from an overall higher scope of work done compared to prior year; and

•	an increase of $2.3 million in transmission expenses primarily due to an increase in costs related to the participation in the MISO RTO.

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•	an increase in transmission construction expenditures due to a greater scope of projects in 2015;

•	an increase in fossil-fueled generation construction expenditures primarily due to a greater scope of work during plant outages in 2015; and

•	money pool activity.

(a)	Calculation excludes the securitization bonds, which are non-recourse to Entergy Texas.

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(a)	See Note 12 to the financial statements in the Form 10-K for additional discussion of the stock-based compensation plans.

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(b)	Maximum amount of shares that may yet be repurchased relates only to the $500 million plan and does not include an estimate of the amount of shares that may be purchased to fund the exercise of grants under the stock-based compensation plans.

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