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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;

•	long-term risks and uncertainties associated with the termination of the System Agreement in 2016, including the potential absence of federal authority to resolve certain issues among the Utility operating companies and their retail regulators;

•

regulatory and operating challenges and uncertainties and economic risks associated with the Utility operating companies’ participation in MISO, including the effect of current or projected MISO market rules and market 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 or the U.S. Department of Justice;

•	changes in the regulation or regulatory oversight of Entergy’s nuclear generating facilities and nuclear materials and fuel, including with respect to the planned potential or actual 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 and the effect of public and political opposition on these applications, regulatory proceedings, and litigation;

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

•	the operation and maintenance of Entergy’s nuclear generating facilities require the commitment of substantial human and capital resources that can result in increased costs and capital expenditures;

•	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 laws and regulations or associated litigation, including requirements for reduced emissions of sulfur dioxide, nitrogen oxide, greenhouse gases, mercury, particulate matter, heat, and other regulated air and water emissions, and changes in costs of compliance with environmental laws and regulations;

•	the effects of changes in federal, state or local laws and regulations, and other governmental actions or policies, including changes in monetary, fiscal, tax, environmental, or energy policies;

•	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 and nuclear waste disposal fees charged by the U.S. government or other providers 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, including the potential for increases in sea levels or coastal land and wetland loss;

•	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, including power prices, 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 and regulatory requirements for the issuance of securities, particularly as they affect access to capital and Entergy’s ability to refinance existing securities, 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 effects, including increased security costs, of threatened or actual terrorism, cyber-attacks or data security breaches, natural or man-made electromagnetic pulses that affect transmission or generation infrastructure, accidents, 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 and the effects on benefits costs 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, requirements for, or cost to decommission Entergy’s nuclear plant sites and the implementation of decommissioning of such sites following shutdown;

•	the decision to cease merchant power generation at all Entergy Wholesale Commodities nuclear power plants by as early as 2021, including the implementation of the planned shutdown of Pilgrim, Palisades, Indian Point 2, and Indian Point 3;

•	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 strategic transactions Entergy may undertake, including mergers, acquisitions, or divestitures, regulatory or other limitations imposed as a result of any such strategic transaction, and the success of the business following any such strategic transaction.

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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.

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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. See “Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for discussion of the operation and planned shutdown or sale of each of the Entergy Wholesale Commodities nuclear power plants.

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

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•	the implementation of formula rate plan rates at Entergy Arkansas, as approved by the APSC, effective with the first billing cycle of January 2017;

•	the implementation of the transmission cost recovery factor rider at Entergy Texas, effective September 2016, and an increase in the transmission cost recovery factor rider rate, effective March 2017, as approved by the PUCT; and

•	an increase in rates at Entergy Mississippi, as approved by the MPSC, effective with the first billing cycle of July 2016.

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(a)

The reduction in owned capacity is due to Entergy’s sale of the 838 MW FitzPatrick plant to Exelon in March 2017 and Entergy’s sale of its 50% membership interest in Top Deer Wind Ventures, LLC in November 2016. See Note 13 to the financial statements herein for discussion of the FitzPatrick sale and Note 14 to the financial statements in the Form 10-K for discussion of the Top Deer Wind Ventures, LLC sale.

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an increase of $18 million in nuclear generation expenses primarily due to higher nuclear labor costs, including contract labor, primarily due to increased operating costs to position the nuclear fleet to meet its operational goals, partially offset by a decrease in regulatory compliance costs. The decrease in regulatory compliance costs is primarily related to additional NRC inspection activities in 2016 as a result of the NRC’s March 2015 decision to move ANO into the “multiple/repetitive degraded cornerstone column” of the NRC’s reactor oversight process action matrix. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of the increased operating costs to position the nuclear fleet to meet its operational goals. 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 subsequent NRC reviews; and

•	an increase of $8 million in transmission and distribution expenses due to higher vegetation maintenance costs in second quarter 2017 as compared to second quarter 2016.

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

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•	an increase in base rates effective February 24, 2016 and the implementation of formula rate plan rates effective with the first billing cycle of January 2017 at Entergy Arkansas, each as approved by the APSC. A significant portion of the base rate increase was related to the purchase of Power Block 2 of the Union Power Station in March 2016;

•	an increase in formula rate plan revenues for Entergy Louisiana, implemented with the first billing cycle of March 2016, to collect the estimated first-year revenue requirement related to the purchase of Power Blocks 3 and 4 of the Union Power Station in March 2016;

•	the implementation of the transmission cost recovery factor rider at Entergy Texas, effective September 2016, and an increase in the transmission cost recovery factor rider rate, effective March 2017, as approved by the PUCT;

•	an increase in rates at Entergy Mississippi, as approved by the MPSC, effective with the first billing cycle of July 2016; and

•	an increase in the purchased power and capacity acquisition cost recovery rider for Entergy New Orleans, as approved by the City Council, effective with the first billing cycle of March 2016, primarily related to the purchase of Power Block 1 of the Union Power Station in March 2016.

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(a)

The reduction in owned capacity is due to Entergy’s sale of the 838 MW FitzPatrick plant to Exelon in March 2017 and Entergy’s sale of its 50% membership interest in Top Deer Wind Ventures, LLC in November 2016. See Note 13 to the financial statements herein for discussion of the FitzPatrick sale and Note 14 to the financial statements in the Form 10-K for discussion of the Top Deer Wind Ventures, LLC sale.

•

an increase of $18 million in nuclear generation expenses primarily due to higher nuclear labor costs, including contract labor, primarily due to increased operating costs to position the nuclear fleet to meet its operational goals, and additional training and initiatives to support management’s operational goals at Grand Gulf, partially offset by a decrease in regulatory compliance costs. The decrease in regulatory compliance costs is primarily related to additional NRC inspection activities in 2016 as a result of the NRC’s March 2015 decision to move ANO into the “multiple/repetitive degraded cornerstone column” of the NRC’s reactor oversight process action matrix. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of the increased operating costs to position the nuclear fleet to meet its operational goals. 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 subsequent NRC reviews;

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the deferral in first quarter 2016 of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance, as approved by the APSC in February 2016 as part of the Entergy Arkansas 2015 rate case settlement. These costs are being amortized over a ten-year period beginning March 2016. See Note 2 to the financial statements in the Form 10-K for further discussion of the rate case settlement;

•	an increase of $11 million in compensation and benefits costs primarily due to a downward revision to estimated incentive compensation expense in first quarter 2016 and an increase in net periodic pension and other postretirement benefits costs as a result of lower discount rates;

•	an increase of $10 million in transmission and distribution expenses due to higher vegetation maintenance costs in 2017; and

•	an increase of $5 million in information technology expenses including software maintenance costs and upgrade projects.

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FitzPatrick’s nuclear refueling outage expenses and expenditures for capital assets being classified as other operation and maintenance expenses as a result of the sales and reimbursement agreements Entergy entered into with Exelon. These costs would have not been incurred absent the sales agreement with Exelon because Entergy planned to shut the plant down in January 2017. The expenses were offset by revenue realized pursuant to the reimbursement agreement and had no effect on net income. See Note 13 to the financial statements herein and Note 14 to the financial statements in the Form 10-K for discussion of the reimbursement agreement;

•	the effect of recording in 2016 final court decisions in litigation against the DOE for the reimbursement of spent nuclear fuel storage costs, which reduced other operation and maintenance expenses in 2016 by $42 million. See Note 8 to the financial statements in the Form 10-K for discussion of the DOE litigation; and

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an increase of $39 million in severance and retention costs in the six months ended June 30, 2017 as compared to the six months ended June 30, 2016 due to management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” below and in the Form 10-K for a discussion of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet.

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

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•	an increase of $160 million in spending on nuclear refueling outages in 2017 as compared to the same period in 2016;

•	lower Entergy Wholesale Commodities net revenue, excluding the effect of revenues resulting from the FitzPatrick reimbursement agreement with Exelon, in 2017 as compared to the same period in 2016, as discussed above. See Note 13 to the financial statements herein and Note 14 to the financial statements in the Form 10-K for discussion of the reimbursement agreement;

•	a decrease due to the timing of recovery of fuel and purchased power costs in 2017 as compared to the same period in 2016. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of fuel and purchased power cost recovery;

•	an increase of $94 million in severance and retention payments in 2017 as compared to the same period in 2016. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Entergy Wholesale Commodities Exit from the Merchant Power Business” above and in the Form 10-K for a discussion of management’s strategy to reduce the size of the Entergy Wholesale Commodities’ merchant fleet; and

•	a refund to customers in January 2017 of approximately $71 million as a result of the settlement approved by the LPSC related to the Waterford 3 replacement steam generator project. See Note 2 to the financial statements herein and in the Form 10-K for discussion of the settlement and refund.

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income tax refunds of $15 million in 2017 compared to income tax payments of $85 million in 2016. Entergy received income tax refunds in 2017 resulting from the carryback of net operating losses. Entergy made income tax payments in 2016 related to the effect of the 2006-2007 IRS audit and for jurisdictions that do not have net operating loss carryovers or jurisdictions in which the utilization of net operating loss carryovers are limited. See Note 3 to the financial statements in the Form 10-K for a discussion of the income tax audit;

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a decrease of $76 million in interest paid in 2017 as compared to the same period in 2016 primarily due to an interest payment of $60 million made in March 2016 related to the purchase of a beneficial interest in the Waterford 3 leased assets. See Note 10 to the financial statements in the Form 10-K for a discussion of Entergy Louisiana’s purchase of a beneficial interest in the Waterford 3 leased assets; and

•	a decrease of $23 million in spending in 2017 as compared to the same period in 2016 on activities related to the decommissioning of Vermont Yankee, which ceased power production in December 2014.

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an increase of $425 million in construction expenditures, primarily in the Utility business. The increase in construction expenditures in the Utility business is primarily due to an increase of $251 million in fossil-fueled generation construction expenditures primarily due to a higher scope of work performed on various projects in 2017, including the St. Charles Power Station project, an increase of $73 million in nuclear construction expenditures primarily due to increased spending on various nuclear projects in 2017, and an increase of $61 million in distribution construction expenditures primarily due to a higher scope of work performed in 2017 as compared to the same period in 2016;

•	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; and

•	proceeds of $25 million received in 2017 compared to proceeds of $89 million received in 2016 from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously capitalized. See Note 1 to the financial statements herein and Note 8 to the financial statements in the Form 10-K for discussion of the DOE litigation.

•	long-term debt activity providing approximately $170 million of cash in 2017 compared to providing approximately $437 million of cash in 2016.  Included in the long-term debt activity is $475 million in 2017 and $595 million in 2016 for the repayment of borrowings on the Entergy Corporation long-term credit facility; and

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•	a decrease of $67 million in 2017 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, the seller is generally not liable to buyer for any damages. Certain unit-contingent sales include a guarantee of availability. Availability guarantees provide 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.

(c)

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.

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

(e)	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.

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(f)

Assumes the planned shutdown of Palisades on October 1, 2018, planned shutdown of Pilgrim on May 31, 2019, planned shutdown of Indian Point 2 on April 30, 2020, and planned shutdown of Indian Point 3 on April 30, 2021, and reflects the sale of FitzPatrick in March 2017. Assumes NRC license renewals 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 and now operating under its period of extended operations while its application is pending). For a discussion regarding the planned shutdown of the Palisades, Pilgrim, Indian Point 2, and Indian Point 3 plants, see “Entergy Wholesale Commodities Exit from the Merchant Power Business” in the Form 10-K. 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 Form 10-K.

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

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

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

(j)	Includes assumptions on converting a portion of the portfolio to contracted with fixed price cost or discount and excludes non-cash revenue from the amortization of the Palisades below-market purchased power agreement, mark-to-market activity, and service revenues.

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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 June 30, 2017 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.

(c)	The credit facility allows Entergy Arkansas to issue letters of credit against 50% of the borrowing capacity of the facility.

(d)	The credit facility allows Entergy Louisiana to issue letters of credit against 50% of the borrowing capacity of the facility.

(e)	Borrowings under the Entergy Mississippi credit facilities may be secured by a security interest in its accounts receivable at Entergy Mississippi’s option.

(f)	The credit facility allows Entergy New Orleans to issue letters of credit against $10 million of the borrowing capacity of the facility.

(g)	The credit facility allows Entergy Texas to issue letters of credit against 50% of the borrowing capacity of the facility.

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(a)	As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. See Note 8 to the financial statements for discussion of financial transmission rights.

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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 Louisiana River Bend does not issue commercial paper, but borrows directly on its bank credit facility.

(b)	Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Arkansas VIE as of June 30, 2017 was $14.7 million.

(c)	Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for Entergy Louisiana Waterford VIE as of June 30, 2017 was $34.5 million.

(d)	Includes borrowings on the credit facility and commercial paper. Commercial paper is classified as a current liability and the amount outstanding for System Energy VIE as of June 30, 2017 was $53.2 million.

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(a)	The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, 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 herein and are based on prices derived from inputs such as benchmark yields and reported trades.

(a)	The values exclude lease obligations of $57 million at Entergy Louisiana and $34 million at System Energy and long-term DOE obligations of $182 million at Entergy Arkansas, 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 herein 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 Corporation and Subsidiaries’ Consolidated Balance Sheet

(d)	Excludes cash collateral in the amount of $1 million posted and $3 million held as of June 30, 2017 and $2 million posted as of December 31, 2016. Also excludes $19 million in letters of credit held as of June 30, 2017.

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(a)	Before taxes of $4 million and $16 million for the three months ended June 30, 2017 and 2016, respectively

(a)	Before taxes of $22 million and $70 million for the six months ended June 30, 2017 and 2016, 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 financial transmission rights 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 financial transmission rights for the Utility operating companies are settled are recovered or refunded through fuel cost recovery mechanisms.

(c)	Amount of gain (loss) recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items.

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(a)	As of June 30, 2017, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi. As of December 31, 2016, letters of credit posted with MISO covered financial transmission rights exposure of $0.3 million for Entergy Arkansas and $0.1 million for Entergy Mississippi.

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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 financial transmission rights for the Utility operating companies are recorded through purchased power expense and then such amounts are

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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 or remaining maturity of three months or less at the date of purchase.

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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:

–	quoted prices for similar assets or liabilities in active markets;

–	quoted prices for identical assets or liabilities in inactive markets;

–	inputs other than quoted prices that are observable for the asset or liability; or

–	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

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

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(b)	Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

(a)	Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($0.1) million for the three months ended June 30, 2017 and ($6) million for the three months ended June 30, 2016.

(a)	Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is $0.3 million for the six months ended June 30, 2017. For the six months ended June 30, 2016, there is no change in unrealized gains or losses included in earnings for derivatives held at the end of the reporting period.

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

(b)	Common trust funds are not publicly quoted, and are valued by the fund administrators using net asset value as a practical expedient. Accordingly, these funds are not assigned a level in the fair value table. The fund administrator of these investments allows daily trading at the net asset value and trades settle at a later date.

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•	a decrease of $5.1 million in fossil-fueled generation expenses primarily due to lower long-term service agreement costs; and

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a decrease of $2.7 million in nuclear generation expenses primarily due to a decrease in regulatory compliance costs, partially offset by higher nuclear labor costs, including contract labor, in second quarter 2017 as compared to second quarter 2016 primarily due to increased operating costs to position the nuclear fleet to meet its operational goals. The decrease in regulatory compliance costs is primarily related to additional NRC inspection

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the deferral in first quarter 2016 of $7.7 million of previously-incurred costs related to ANO post-Fukushima compliance and $9.9 million of previously-incurred costs related to ANO flood barrier compliance, as approved by the APSC as part of the 2015 rate case settlement. These costs are being amortized over a ten-year period beginning March 2016. See Note 2 to the financial statements in the Form 10-K for further discussion of the rate case settlement;

•	an increase of $5.4 million in transmission and distribution expenses due to higher vegetation maintenance costs in 2017; and

•	an increase of $4 million in compensation and benefits costs primarily due to a downward revision to estimated incentive compensation expense in first quarter 2016 and an increase in net periodic pension and other postretirement benefits costs as a result of a lower discount rate.

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•	an increase of $56.6 million in nuclear construction expenditures primarily due to a higher scope of work performed on various nuclear projects in 2017;

•	an increase of $17.8 million in fossil-fueled generation construction expenditures primarily due to a higher scope of work performed on various projects in 2017; and

•	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 service deliveries, and the timing of cash payments during the nuclear fuel cycle.

•	a $200 million capital contribution received from Entergy Corporation in March 2016 primarily in anticipation of Entergy Arkansas’s purchase of Power Block 2 of the Union Power Station;

•	the issuance of $325 million of 3.5% Series first mortgage bonds in January 2016, a portion of the proceeds of which were used to pay, prior to maturity, $175 million of 5.66% Series first mortgage bonds; and

•	the issuance of $55 million of 3.5% Series first mortgage bonds in June 2016.

•	the issuance of $220 million of 3.5% Series first mortgage bonds in May 2017;

•	net borrowings of $31.4 million on the Entergy Arkansas nuclear fuel company variable interest entity credit facility in 2017 compared to net borrowings of $0.9 million in 2016; and

•	money pool activity.

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

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an increase of $3.8 million in nuclear generation expenses primarily due to higher nuclear labor costs, including contract labor, primarily due to increased operating costs to position the nuclear fleet to meet its operational goals, partially offset by a lower scope of work performed during plant outages in the second quarter 2017 as compared to the second quarter 2016. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of the increased operating costs to position the nuclear fleet to meet its operational goals;

•	an increase of $2.6 million in transmission and distribution expenses due to higher vegetation maintenance costs;

•	an increase of $1.9 million due to the effect of recording in 2016 a final court decision in the Entergy Louisiana lawsuit against the DOE related to the River Bend spent nuclear fuel storage costs. The damages awarded included the reimbursement in 2016 of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense;

•	an increase of $1 million as a result of the amount of transmission costs allocated by MISO. See Note 2 to the financial statements herein and in the Form 10-K for further information on the recovery of these costs; and

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•	several individually insignificant items.

•	an increase of $3.9 million in compensation and benefits costs primarily due to a downward revision to estimated incentive compensation expense in first quarter 2016;

•	an increase of $3.5 million in fossil-fueled generation expenses primarily due to the purchase of Power Blocks 3 and 4 of the Union Power Station in March 2016, partially offset by asbestos loss provisions in 2016;

•	an increase of $2.9 million in other loss provisions in 2017;

•	an increase of $2.2 million in information technology expenses including software maintenance costs and upgrade projects;

•	an increase of $2.1 million in transmission expenses primarily due to higher labor costs, including contract labor;

•	an increase of $2.1 million as a result of the amount of transmission costs allocated by MISO. See Note 2 to the financial statements herein and in the Form 10-K for further information on the recovery of these costs;

•	an increase of $1.9 million due to the effect of recording in 2016 a final court decision in the Entergy Louisiana lawsuit against the DOE related to the River Bend spent nuclear fuel storage costs. The damages awarded included the reimbursement in 2016 of spent nuclear fuel storage costs previously recorded as other operation and maintenance expense; and

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an increase of $1.8 million in nuclear generation expenses primarily due to higher nuclear labor costs, including contract labor, primarily due to increased operating costs to position the nuclear fleet to meet its operational goals, partially offset by a lower scope of work performed during plant outages in 2017 as compared to 2016. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS – Nuclear Matters” in the Form 10-K for a discussion of the increased operating costs to position the nuclear fleet to meet its operational goals.

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income tax refunds of $116.9 million in 2017 compared to income tax payments of $62.7 million in 2016. Entergy Louisiana received income tax refunds in 2017 and made income tax payments in 2016 in accordance with an intercompany income tax allocation agreement. The income tax refunds in 2017 resulted from the utilization of Entergy Louisiana’s net operating losses. The income tax payments in 2016 related to the 2016 payments for state taxes resulting from the effect of the final settlement of the 2006-2007 IRS audit and the effect of net operating loss limitations. See Note 3 to the financial statements in the Form 10-K for a discussion of the audit. See “MANAGEMENT’S FINANCIAL DISCUSSION AND ANALYSIS - Louisiana Tax Legislation” in the Form 10-K for a discussion on the net operating loss limitations;

•	an interest payment of $60 million made in March 2016 related to the purchase of a beneficial interest in the Waterford 3 leased assets; and

•	the timing of collections from customers and payments to vendors.

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•	a refund to customers in January 2017 of approximately $71 million as a result of the settlement approved by the LPSC related to the Waterford 3 replacement steam generator project. See Note 2 to the financial statements herein and in the Form 10-K for discussion of the settlement and refund;

•	a decrease due to the timing of recovery of fuel and purchased power costs in 2017; and

•	an increase of $47.8 million in spending on nuclear refueling outages in 2017.

•	an increase of $205.5 million in fossil-fueled generation construction expenditures primarily due to higher spending on the St. Charles Power Station project in 2017;

•	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 service deliveries, and the timing of cash payments during the nuclear fuel cycle;

•	an increase of $75.8 million in transmission construction expenditures due to a higher scope of work performed in 2017 as compared to the same period in 2016;

•	an increase of $44.1 million in nuclear construction expenditures primarily due to increased spending on various nuclear projects in 2017; and

•	money pool activity.

•	net borrowings of $30.7 million on the nuclear fuel company variable interest entities’ credit facilities in 2017 compared to net repayments of $0.9 million in 2016; and

•	a decrease of $14.3 million of common equity distributions primarily as a result of higher construction expenditures and higher nuclear fuel purchases in 2017 as compared to the same period in 2016.

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

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•	an increase of $41.5 million in transmission construction expenditures primarily due to a higher scope of work performed in 2017 as compared to the same period in 2016;

•	an increase of $10.4 million in distribution construction expenditures primarily due to a higher scope of non-storm related work performed in 2017 as compared to the same period in 2016; and

•	an increase of $7.4 million in storm spending in 2017.

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•	a decrease of $2.4 million in other loss provisions; and

•	a decrease of $2 million in fossil-fueled generation expenses primarily due to the deactivation of Michoud Units 2 and 3 effective May 2016 and asbestos loss provisions recorded in second quarter 2016.

•	a decrease of $2.8 million in fossil-fueled generation expenses primarily due to the deactivation of Michoud Units 2 and 3 effective May 2016 and asbestos loss provisions recorded in 2016, partially offset by an increase as a result of the purchase of Power Block 1 of the Union Power Station in March 2016; and

•	a decrease of $2 million in other loss provisions.

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•	the issuance of $110 million of 5.50% Series first mortgage bonds in March 2016;

•	the issuance of $85 million of 4% Series first mortgage bonds in May 2016. Entergy New Orleans used the proceeds to pay, prior to maturity, its $33.271 million of 5.6% Series first mortgage bonds due September 2024 and to pay, prior to maturity, its $37.772 million of 5.65% Series first mortgage bonds due September 2029;

•	a $47.8 million capital contribution received from Entergy Corporation in March 2016 in anticipation of Entergy New Orleans’s purchase of Power Block 1 of the Union Power Station. See Note 14 to the financial statements in the Form 10-K for discussion of the Union Power Station purchase; and

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•	$24.2 million in common stock dividends paid in 2017 as compared to $7 million in common stock dividends paid in 2016. There were no common stock dividends paid in first quarter 2016 in anticipation of the purchase of Power Block 1 of the Union Power Station in March 2016.

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

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•	an increase of $2 million in transmission and distribution expenses due to higher vegetation maintenance costs;

•	an increase of $1.2 million in fossil-fueled generation expenses primarily due to a higher scope of work done during plant outages in 2017 compared to the same period in 2016; and

•	an increase of $0.7 million in energy efficiency costs.

•	an increase of $1.8 million in transmission and distribution expenses due to higher vegetation maintenance costs;

•	an increase of $1.4 million in customer service costs;

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•	an increase of $1.3 million in fossil-fueled generation expenses primarily due to a higher scope of work done during plant outages in 2017 as compared to the same period in 2016;

•	an increase of $1.2 million in information technology expenses including software maintenance costs and upgrade projects;

•	an increase of $0.9 million in compensation and benefits costs primarily due to a downward revision to estimated incentive compensation expense in first quarter 2016; and

•	an increase of $0.7 million in energy efficiency costs.

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•	a decrease of $49 million in transmission construction expenditures primarily due to a lower scope of work performed in 2017 as compared to the same period in 2016, partially offset by an increase in baseline work performed in 2017 as compared to the same period in 2016; and

•	money pool activity.

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

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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; and

•	a decrease of $28.1 million in nuclear construction expenditures primarily as a result of a higher scope of work performed in 2016 on Grand Gulf outage projects and lower spending in 2017 on compliance with NRC post-Fukushima requirements.

•	common stock dividends and distributions of $139 million in 2016 in order to maintain the targeted capital structure; and

•	the partial repayment caused by System Energy in May 2016 of $22 million of 5.875% pollution control revenue bonds due 2022 issued on behalf of System Energy.

•	a decrease in net borrowings of $63.3 million on the nuclear fuel company variable interest entity’s credit facility in 2017 compared to the same period in 2016; and

•	the payment in February 2017, at maturity, of $50 million of the System Energy nuclear fuel company variable interest entity’s 4.02% Series H notes.

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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.

(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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