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•	resolution of pending and future rate cases, formula rate proceedings and related 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 benefits of continued MISO participation, 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 with respect to 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 Entergy’s nuclear generating facilities;

•	increases in costs and capital expenditures that could result from the commitment of substantial human and capital resources required for the operation and maintenance of Entergy’s 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, especially in light of the planned shutdown or sale of each of these 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;

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•	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;

•	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, agency positions 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, requirements for waste management and disposal and for the remediation of contaminated sites, wetlands protection and permitting, and changes in costs of compliance with these environmental laws and regulations;

•	changes in laws and regulations, agency positions, or associated litigation related to protected species and associated critical habitat designations;

•	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, trade/tariff, 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 northern 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;

•	federal income tax reform, including the enactment of the Tax Cuts and Jobs Act, and its intended and unintended consequences on financial results and future cash flows, including the potential impact to credit ratings, which may affect Entergy’s ability to borrow funds or increase the cost of borrowing in the future;

•	the effects of Entergy’s strategies to reduce tax payments, especially in light of federal income tax reform;

•	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 (i) Entergy’s ability to implement new technologies, (ii) the impact of changes relating to new, developing, or alternative sources of generation such as distributed energy and energy storage, energy efficiency, demand side management, and other measures that reduce load, and (iii) competition from other companies offering products and services to our customers based on new or emerging technologies;

•	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, directors, and employees with specialized skills;

•	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;

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•	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 mid-2022, including the implementation of the planned shutdowns of Pilgrim, Indian Point 2, Indian Point 3, and Palisades;

•	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, divestitures, or restructurings, 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.

•

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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•	an increase in formula rate plan rates effective with the first billing cycle of January 2018 at Entergy Arkansas, as approved by the APSC;

•	higher storm damage rider revenues at Entergy Mississippi;

•	an increase in energy efficiency revenues; and

•	increases in the distribution cost recovery factor rider rate in September 2017 at Entergy Texas, as approved by the PUCT.

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•	an increase of $17 million in fossil-fueled generation expenses primarily due to an overall higher scope of work performed during outages in second quarter 2018 as compared to second quarter 2017;

•	an increase of $5 million in energy efficiency costs; and

•	an increase of $5 million in storm damage provisions, primarily at Entergy Mississippi. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of storm cost recovery.

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

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•	an increase in formula rate plan rates effective with the first billing cycle of January 2018 at Entergy Arkansas, as approved by the APSC;

•	an increase in energy efficiency revenues;

•	higher storm damage rider revenues at Entergy Mississippi; and

•	increases in the distribution cost recovery factor rider rate in September 2017 at Entergy Texas, as approved by the PUCT.

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•

a decrease resulting from the reimbursement agreement with Exelon pursuant to which Exelon reimbursed Entergy in the first quarter 2017 for specified out-of-pocket costs associated with preparing for the refueling and operation of FitzPatrick that otherwise would have been avoided had Entergy shut down FitzPatrick in January 2017. Revenues received from Exelon under the reimbursement agreement were offset by other operation and maintenance expenses and taxes other than income taxes and had no effect on net income. See Note 14 to the financial statements in the Form 10-K for discussion of the sale of FitzPatrick and the reimbursement agreement with Exelon; and

•	lower realized wholesale energy prices, partially offset by higher capacity prices.

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•	an increase of $23 million in fossil-fueled generation expenses primarily due to an overall higher scope of work performed during outages in 2018 as compared to 2017;

•	an increase of $13 million in nuclear generation expenses primarily due to a higher scope of work performed during plant outages in 2018 as compared to the same period in 2017 and higher nuclear labor costs, including contract labor, to position the nuclear fleet to meet its operational goals;

•	an increase of $13 million in energy efficiency costs;

•	an increase of $12 million in storm damage provisions, primarily at Entergy Mississippi. See Note 2 to the financial statements herein and in the Form 10-K for discussion of storm cost recovery; and

•	an increase of $8 million in vegetation maintenance costs.

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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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•	a decrease of $126 million in spending on nuclear refueling outages in 2018 as compared to the same period in 2017;

•	severance and retention payments of $92 million in 2017. See Note 7 to the financial statements herein for a discussion of severance and retention costs in connection with management’s strategy to manage and reduce the risk of the Entergy Wholesale Commodities business;

•	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 in the Form 10-K for discussion of the settlement and refund;

•	the effect of favorable weather on billed Utility sales in 2018; and

•	a decrease of $16 million in pension contributions 2018 as compared to the same period in 2017. 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.

•	lower Entergy Wholesale Commodities net revenue in 2018 as compared to the same period in 2017 (except for the revenues resulting from the FitzPatrick reimbursement agreement with Exelon), as discussed above. See Note 14 to the financial statements in the Form 10-K for discussion of the reimbursement agreement;

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•	the return of unprotected excess accumulated deferred income taxes to Utility customers. See Note 2 to the financial statements herein and in the Form 10-K for a discussion of the regulatory activity regarding the Tax Cuts and Jobs Act;

•	an increase of $28 million in interest paid in 2018 as compared to the same period in 2017 resulting from an increase in interest expense;

•	income tax payments of $14 million in 2018 compared to income tax refunds of $15 million in 2017. Entergy made income tax payments in 2018 for estimated federal income taxes. Entergy received income tax refunds in 2017 resulting from the carryback of net operating losses; and

•	proceeds of $23 million received in 2017 from the DOE resulting from litigation regarding spent nuclear fuel storage costs that were previously expensed. See Note 8 to the financial statements in the Form 10-K for discussion of the spent nuclear fuel litigation.

•

an increase of $166 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 $123 million in fossil-fueled generation construction expenditures primarily due to higher spending in 2018 on the Lake Charles Power Station project and an increase of $39 million in nuclear construction expenditures primarily due to a higher scope of work performed on Grand Gulf outage projects in 2018;

•	proceeds of $100 million from the sale in March 2017 of the FitzPatrick plant to Exelon. See Note 14 to the financial statements in the Form 10-K for a discussion of the sale of FitzPatrick; and

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

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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 the 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, the 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.

(f)	Assumes the planned shutdown of Pilgrim on May 31, 2019, planned shutdown of Indian Point 2 on April 30, 2020, planned shutdown of Indian Point 3 on April 30, 2021, and planned shutdown of Palisades on May 31, 2022. Assumes NRC license renewals for two units, as follows (with current license expirations in parentheses):

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(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 mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation;

•	a 9.8% target earned return on common equity for the 2018 and 2019 test years;

•	narrowing of the common equity bandwidth to plus or minus 60 basis points around the target earned return on common equity;

•	a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity);

•	a framework for the flow back of certain tax benefits created by the Tax Act to customers, as described in “Regulatory activity regarding the Tax Cuts and Jobs Act” above; and

•	a transmission recovery mechanism providing for the opportunity to recover certain transmission related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism.

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•	Entergy Mississippi would redeem its outstanding preferred stock, at the aggregate redemption price of approximately $21.2 million, including call premiums, plus accumulated and unpaid dividends, if any.

•	Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation.

•

Under the Texas Business Organizations Code (TXBOC), Entergy Mississippi will allocate substantially all of its assets to a new subsidiary, Entergy Mississippi Power and Light, LLC, a Texas limited liability company (Entergy Mississippi Power and Light), and Entergy Mississippi Power and Light will assume substantially all of the liabilities of Entergy Mississippi, in a transaction regarded as a merger under the TXBOC. Entergy Mississippi will remain in existence and hold the membership interests in Entergy Mississippi Power and Light.

•	Entergy Mississippi will contribute the membership interests in Entergy Mississippi Power and Light to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy Mississippi Power and Light will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC.

•	Entergy Mississippi will change its name to Entergy Utility Enterprises, Inc., and Entergy Mississippi Power and Light will then change its name to Entergy Mississippi, LLC.

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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)	For credit facilities with no borrowings as of June 30, 2018, the interest rate is the estimated interest rate as of June 30, 2018 that would have been applied 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 includes fronting commitments for the issuance of letters of credit against a portion of the borrowing capacity of the facility as follows: $5 million for Entergy Arkansas; $15 million for Entergy Louisiana; $10 million for Entergy New Orleans; and $30 million for Entergy Texas.

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

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(a)	As of June 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.6 million for Entergy Arkansas and $0.2 million for Entergy Mississippi. See Note 8 to the financial statements herein 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)	The total amount outstanding as of June 30, 2018 is commercial paper, and is classified as a current liability.

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(a)	The values exclude lease obligations of $34 million at System Energy and long-term DOE obligations of $185 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.

(a)	The values exclude the lease obligations of $34 million at System Energy and long-term DOE obligations of $183 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.

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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 $5 million posted and $3 million held as of June 30, 2018 and $1 million posted and $4 million held as of December 31, 2017. Also excludes letters of credit in the amount of $1 million posted and $3 million held as of June 30, 2018 and $34 million in letters of credit held as of December 31, 2017.

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(a)	Before taxes of $1 million and $4 million for the three months ended June 30, 2018 and 2017, respectively

(a)	Before taxes of ($6) million and $22 million for the six months ended June 30, 2018 and 2017, 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 recognized in accumulated other comprehensive income from electricity swaps and options de-designated as hedged items.

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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 Registrant Subsidiaries’ balance sheets

(d)	As of June 30, 2018, letters of credit posted with MISO covered financial transmission rights exposure of $0.6 million for Entergy Arkansas and $0.2 million for Entergy Mississippi. As of December 31, 2017, letters of

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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.

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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.

•

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 estimate of fair value for the asset or liability.  Level 3 consists primarily of financial transmission rights 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 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)	Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($0.8) million for the three months ended June 30, 2018 and ($0.1) million for the three months ended June 30, 2017.

(a)	Change in unrealized gains or losses for the period included in earnings for derivatives held at the end of the reporting period is ($0.7) million for the six months ended June 30, 2018 and $0.3 million for the six months ended June 30, 2017.

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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 herein 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)	Sales for resale and competitive businesses sales include day-ahead sales of energy in a market administered by an ISO. These sales represent financially binding commitments for the sale of physical energy the next day. These sales are adjusted to actual power generated and delivered in the real time market. Given the short

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(b)	Other electric revenues consist primarily of transmission and ancillary services provided to participants of an ISO-administered market and unbilled revenue.

(c)	Non-customer revenues include the settlement of financial hedges, occasional sales of inventory, alternative revenue programs, provisions for revenue subject to refund, and late fees.

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•	an increase of $5.7 million in fossil-fueled generation expenses primarily due to a higher scope of work performed during plant outages in 2018 as compared to the same period in 2017;

•	higher energy efficiency expenses of $3.8 million due to the timing of recovery from customers in 2017; and

•	an increase of $1.4 million in nuclear generation expenses primarily due to higher labor costs, including contract labor, to position the nuclear fleet to meet its operational goals. 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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•	an increase of $8 million in nuclear generation expenses primarily due to higher labor costs, including contract labor, to position the nuclear fleet to meet its operational goals. 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;

•	higher energy efficiency expenses of $7.9 million due to the timing of recovery from customers; and

•	an increase of $4.2 million in fossil-fueled generation expenses primarily due to a higher scope of work performed during plant outages in 2018 as compared to the same period in 2017.

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•	a decrease of $49.5 million as a result of the 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 decrease of $16.3 million in storm spending;

•	a decrease of $11.7 million in nuclear construction expenditures primarily due to a lower scope of work performed on various nuclear projects in 2018 as compared to the same period in 2017;

•	a decrease of $9.4 million in transmission construction expenditures due to a decrease in spending on various transmission projects in 2018 as compared to the same period in 2017; and

•	a decrease of $9.1 million in fossil-fueled generation construction expenditures due to a decrease in spending on various fossil-fueled generation projects in 2018 as compared to the same period in 2017.

•	a $350 million capital contribution from Entergy Corporation in 2018 in anticipation of the return of unprotected excess accumulated deferred income taxes to customers and upcoming planned capital investments; and

•	net borrowings of $16.8 million in 2018 on the Entergy Arkansas nuclear fuel company variable interest entity.

•	money pool activity; and

•	net repayments of short-term borrowings of $50 million on the Entergy Arkansas nuclear fuel company variable interest entity credit facility in 2018 as compared to net short-term borrowings of $31.4 million on the Entergy Arkansas nuclear fuel company variable interest entity credit facility in 2017.

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

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•	an increase of $19.1 million in fossil-fueled generation expenses primarily due to an overall higher scope of work performed during plant outages in 2018 as compared to the same period in 2017; and

•	an increase of $10.6 million in nuclear generation expenses primarily due to higher nuclear labor costs, including contract labor, to position the nuclear fleet to meet its operational goals and a higher scope of work performed during plant outages in 2018 as compared to the same period in 2017.

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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 in the Form 10-K for discussion of the settlement and refund; and

•	a decrease of $63.1 million in spending on nuclear refueling outages.

•	a decrease of $114 million in income tax refunds in 2018 as compared to the same period in 2017. Entergy Louisiana received income tax refunds in 2017 in accordance with an intercompany income tax allocation agreement resulting from the utilization of Entergy Louisiana’s net operating losses;

•	the return of unprotected excess accumulated deferred income taxes to customers. See Note 2 to the financial statements herein for a discussion of the regulatory activity regarding the Tax Cuts and Jobs Act; and

•	a decrease due to the timing of recovery of fuel and purchased power costs.

•	a decrease of $148.9 million as a result of 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;

•	money pool activity; and

•	a decrease of $23.3 million in nuclear construction expenditures primarily due to decreased spending on various nuclear projects.

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•	the issuance of $450 million of 3.12% collateral trust mortgage bonds in May 2017. A portion of the proceeds was used to repay $45.3 million of Waterford Series collateral trust mortgage notes;

•	net repayments of short-term borrowings of $43.5 million on the nuclear fuel company variable interest entities’ credit facilities in 2018 compared to net short-term borrowings of $30.7 million in 2017; and

•	net repayments of long-term borrowings of $11.8 million on the nuclear fuel company variable interest entities’ credit facilities in 2018 compared to net borrowings of $51.9 million in 2017.

•	the issuance of $750 million of 4.00% Series first mortgage bonds in March 2018. A portion of the proceeds was used to repay $375 million of 6.0% Series First Mortgage bonds in May 2018; and

•	a decrease of $35.3 million in common equity distributions.

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

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•	a mid-point reset of formula rate plan revenues to a 9.95% earned return on common equity for the 2017 test year and for the St. Charles Power Station when it enters commercial operation;

•	a 9.8% target earned return on common equity for the 2018 and 2019 test years;

•	narrowing of the common equity bandwidth to plus or minus 60 basis points around the target earned return on common equity;

•	a cap on potential revenue increase of $35 million for the 2018 evaluation period, and $70 million for the cumulative 2018 and 2019 evaluation periods, on formula rate plan cost of service rate increases (the cap excludes rate changes associated with the transmission recovery mechanism described below and rate changes associated with additional capacity);

•	a framework for the flow back of certain tax benefits created by the Tax Act to customers; and

•	a transmission recovery mechanism providing for the opportunity to recover certain transmission related expenditures in excess of $100 million annually for projects placed in service up to one month prior to rate change outside of sharing that is designed to operate in a manner similar to the additional capacity mechanism.

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•	the timing of payments to vendors;

•	the timing of recovery of fuel and purchased power costs; and

•	the timing of collection of storm damage rider revenues. See Note 2 to the financial statements herein and in the Form 10-K for further discussion of the storm damage rider.

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•	Entergy Mississippi would redeem its outstanding preferred stock, at the aggregate redemption price of approximately $21.2 million, including call premiums, plus accumulated and unpaid dividends, if any.

•	Entergy Mississippi would convert from a Mississippi corporation to a Texas corporation.

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Under the Texas Business Organizations Code (TXBOC), Entergy Mississippi will allocate substantially all of its assets to a new subsidiary, Entergy Mississippi Power and Light, LLC, a Texas limited liability company (Entergy Mississippi Power and Light), and Entergy Mississippi Power and Light will assume substantially all of the liabilities of Entergy Mississippi, in a transaction regarded as a merger under the TXBOC. Entergy Mississippi will remain in existence and hold the membership interests in Entergy Mississippi Power and Light.

•	Entergy Mississippi will contribute the membership interests in Entergy Mississippi Power and Light to an affiliate (Entergy Utility Holding Company, LLC, a Texas limited liability company and subsidiary of Entergy Corporation). As a result of the contribution, Entergy Mississippi Power and Light will be a wholly-owned subsidiary of Entergy Utility Holding Company, LLC.

•	Entergy Mississippi will change its name to Entergy Utility Enterprises, Inc., and Entergy Mississippi Power and Light will then change its name to Entergy Mississippi, LLC.

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•	a decrease in the purchased power and capacity acquisition cost recovery rider primarily due to a decrease in the revenue requirement related to Power Block 1 of the Union Power Station; and

•	regulatory charges of $1.6 million recorded in the second quarter 2018 as a result of an agreement with the City Council to return the benefits of the lower federal income tax rate in 2018 to customers.

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•	regulatory charges of $3.3 million recorded in 2018 as a result of an agreement with the City Council to return the benefits of the lower federal income tax rate in 2018 to customers; and

•	a decrease in the purchased power and capacity acquisition cost recovery rider primarily due to credits to customers as part of the Entergy New Orleans internal restructuring agreement in principle, effective with the first billing cycle of June 2017.

•	an increase of $2.4 million in distribution expenses primarily due to an overall higher scope of work performed in 2018 as compared to the same period in 2017;

•	an increase of $1.5 million in energy efficiency costs;

•	an increase of $1.5 million in loss provisions; and

•	several individually insignificant items.

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

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•	an increase of $14.2 million in fossil-fueled generation construction expenditures primarily due to increased spending on the Montgomery County Power Station and a higher scope of work performed in 2018 as compared to the same period in 2017; and

•	an increase of $4.4 million in transmission construction expenditures primarily due to a higher scope of work performed in 2018 as compared to the same period in 2017.

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

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•	higher other income primarily due to an increase in the allowance for equity funds used during construction resulting from spending on Grand Gulf outage projects in 2018;

•	the increase in operating revenues resulting from changes in rate base as compared to the same period in prior year; and

•	a lower effective income tax rate.

•	higher other income primarily due to an increase in the allowance for equity funds used during construction resulting from spending on Grand Gulf outage projects in 2018;

•	the increase in operating revenues resulting from changes in rate base as compared to the same period in prior year; and

•	a lower effective income tax rate.

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•	the issuance in March 2018 of $100 million of 3.42% Series J notes by the System Energy nuclear fuel company variable interest entity;

•	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;

•	common stock dividends and distributions of $63.2 million in 2018 in order to maintain the targeted capital structure;

•	net repayments of long-term borrowings of $50 million in 2018 on the nuclear fuel company variable interest entity’s credit facility; and

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•	net short-term borrowings of $21 million in the six months ended June 30, 2018 compared to net short-term borrowings of $36.3 million in the six months ended June 30, 2017 on the nuclear fuel company variable interest entity’s credit facility.

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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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(a)	Earnings, as defined, for the six months ended June 30, 2018 were $46.5 million less than fixed charges, as defined.

(b)	Earnings, as defined, for the six months ended June 30, 2018 were $47.1 million less than fixed charges, as defined.

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