Entergy Corporation and Subsidiaries Notes to Financial Statements
## Table 0 ##
The Registrant Subsidiaries’ estimated tax attributes carryovers and their expiration dates as of December 31, 2011 are as follows:
## Table 1 ##
As a result of the accounting for uncertain tax positions, the amount of the deferred tax assets reflected in the financial statements is less than the amount of the tax effect of the federal and state net operating loss carryovers and tax credit carryovers.
NOTE 7.
COMMON EQUITY (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Common Stock Common stock and treasury stock shares activity for Entergy for 2011, 2010, and 2009 is as follows:
## Table 2 ##
In December 2005, Entergy Corporation sold 10 million equity units with a stated amount of $50 each.
An equity unit consisted of (1) a note, initially due February 2011 and initially bearing interest at an annual rate of 5.75%, and (2) a purchase contract that obligated the holder of the equity unit to purchase for $50 between 0.5705 and 0.7074 shares of Entergy Corporation common stock on or before February 17, 2009.
Entergy paid the holders quarterly contract adjustment payments of 1.875% per year on the stated amount of $50 per equity unit.
Under the terms of the purchase contracts, Entergy attempted to remarket the notes in February 2009 but was unsuccessful, the note holders put the notes to Entergy, Entergy retired the notes, and Entergy issued shares of common stock to settle the purchase contracts.
Entergy Corporation reissues treasury shares to meet the requirements of the Stock Plan for Outside Directors (Directors’ Plan), two Equity Ownership Plans of Entergy Corporation and Subsidiaries, the Equity Awards Plan of Entergy Corporation and Subsidiaries, and certain other stock benefit plans.
The Directors’ Plan awards to non-employee directors a portion of their compensation in the form of a fixed number of shares of Entergy Corporation common stock.
In January 2007, the Board approved a repurchase program that authorized Entergy to repurchase up to $1.5 billion of its common stock.
In January 2008, the Board authorized an incremental $500 million share repurchase program to enable Entergy to consider opportunistic purchases in response to equity market conditions.
Entergy completed both the $1.5 billion and $500 million programs in the third quarter 2009.
In October 2009, the Board granted authority for an additional $750 million share repurchase program which was completed in the fourth quarter 2010.
In October 2010, the Board granted authority for an additional $500 million share repurchase program.
As of December 31, 2011, $350 million remains under the $500 million share repurchase program.
Retained Earnings and Dividend Restrictions Provisions within the articles of incorporation or pertinent indentures and various other agreements relating to the long-term debt and preferred stock of certain of Entergy Corporation’s subsidiaries could restrict the payment of cash dividends or other distributions on their common and preferred equity.
As of December 31, 2011, under provisions in their mortgage indentures, Entergy Arkansas and Entergy Mississippi had retained earnings unavailable for distribution to Entergy Corporation of $394.9 million and $68.5 million, respectively.
Entergy Corporation
Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis 3 Net Revenue Utility Following is an analysis of the change in net revenue comparing 2011 to 2010.
## Table 3 ##
The mark-to-market tax settlement sharing variance results from a regulatory charge because a portion of the benefits of a settlement with the IRS related to the mark-to-market income tax treatment of power purchase contracts will be shared with customers, slightly offset by the amortization of a portion of that charge beginning in October 2011.
See Notes 3 and 8 to the financial statements for additional discussion of the settlement and benefit sharing.
The purchased power capacity variance is primarily due to price increases for ongoing purchased power capacity and additional capacity purchases.
The net wholesale revenue variance is primarily due to lower margins on co-owner contracts and higher wholesale energy costs.
The volume/weather variance is primarily due to an increase of 2,061 GWh in weather-adjusted usage across all sectors.
Weather-adjusted residential retail sales growth reflected an increase in the number of customers.
Industrial sales growth has continued since the beginning of 2010.
Entergy’s service territory has benefited from the national manufacturing economy and exports, as well as industrial facility expansions.
Increases have been offset to some extent by declines in the paper, wood products, and pipeline segments.
The increase was also partially offset by the effect of less favorable weather on residential sales.
The ANO decommissioning trust variance is primarily related to the deferral of investment gains from the ANO 1 and 2 decommissioning trust in 2010 in accordance with regulatory treatment.
The gains resulted in an increase in interest and investment income in 2010 and a corresponding increase in regulatory charges with no effect on net income.
The retail electric price variance is primarily due to: x rate actions at Entergy Texas, including a base rate increase effective August 2010 and an additional increase beginning May 2011; x a formula rate plan increase at Entergy Louisiana effective May 2011; and x a base rate increase at Entergy Arkansas effective July 2010.
These were partially offset by formula rate plan decreases at Entergy New Orleans effective October 2010 and October 2011.
See Note 2 to the financial statements for further discussion of these proceedings.
System Energy Resources, Inc.  Management’s Financial Discussion and Analysis 383 Following are the amounts of System Energy’s planned construction and other capital investments, existing debt and lease obligations (includes estimated interest payments), and other purchase obligations:

Tables referenced above, in order (Table 0 first):
<table><tr><td>2010</td><td>Entergy Arkansas</td><td>Entergy Gulf States Louisiana</td><td>Entergy Louisiana</td><td>Entergy Mississippi</td><td>Entergy New Orleans</td><td>Entergy Texas</td><td>System Energy</td></tr><tr><td></td><td colspan="7">(In Thousands)</td></tr><tr><td>Deferred tax liabilities:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Plant basis differences - net</td><td>-$1,213,900</td><td>-$1,114,183</td><td>-$1,135,092</td><td>-$564,928</td><td>-$206,739</td><td>-$881,037</td><td>-$474,446</td></tr><tr><td>Regulatory asset for income taxes - net</td><td>-87,848</td><td>-132,145</td><td>-138,131</td><td>-24,649</td><td>66,251</td><td>-53,906</td><td>-78,836</td></tr><tr><td>Power purchase agreements</td><td>582</td><td>102,581</td><td>-417,388</td><td>-766</td><td>-61</td><td>-6,851</td><td>-</td></tr><tr><td>Nuclear decommissioning trusts</td><td>-9,968</td><td>-978</td><td>-3,806</td><td>-</td><td>-</td><td>-</td><td>-4,102</td></tr><tr><td>Deferred fuel</td><td>-24,210</td><td>-935</td><td>-7,584</td><td>-4,521</td><td>-626</td><td>10,025</td><td>-60</td></tr><tr><td>Other</td><td>-123,524</td><td>-2,505</td><td>-21,971</td><td>-10,991</td><td>-13,839</td><td>-19,712</td><td>-15,234</td></tr><tr><td>Total</td><td>-$1,458,868</td><td>-$1,148,165</td><td>-$1,723,972</td><td>-$605,855</td><td>-$155,014</td><td>-$951,481</td><td>-$572,678</td></tr><tr><td>Deferred tax assets:</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Accumulated deferred investment</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>tax credits</td><td>17,623</td><td>32,651</td><td>29,417</td><td>2,502</td><td>706</td><td>7,327</td><td>20,944</td></tr><tr><td>Pension and OPEB</td><td>-64,774</td><td>70,954</td><td>7,922</td><td>-27,111</td><td>-11,527</td><td>-38,152</td><td>-18,255</td></tr><tr><td>Nuclear decommissioning liabilities</td><td>-173,666</td><td>-41,829</td><td>-</td><td>-</td><td>-</td><td>-</td><td>-69,610</td></tr><tr><td>Sale and leaseback</td><td>-</td><td>-</td><td>80,117</td><td>-</td><td>-</td><td>-</td><td>176,040</td></tr><tr><td>Provision for regulatory adjustments</td><td>-</td><td>100,504</td><td>-</td><td>-</td><td>-</td><td>-</td><td>-</td></tr><tr><td>Unbilled/deferred revenues</td><td>8,056</td><td>-23,853</td><td>6,892</td><td>8,914</td><td>1,538</td><td>15,775</td><td>-</td></tr><tr><td>Customer deposits</td><td>7,907</td><td>618</td><td>5,699</td><td>1,391</td><td>109</td><td>-</td><td>-</td></tr><tr><td>Rate refund</td><td>10,873</td><td>-5,386</td><td>131</td><td>-</td><td>-</td><td>-4,008</td><td>-</td></tr><tr><td>Net operating loss carryforwards</td><td>-</td><td>40</td><td>41</td><td>-</td><td>8</td><td>139,859</td><td>-</td></tr><tr><td>Other</td><td>13,589</td><td>26,468</td><td>25,897</td><td>14,585</td><td>21,310</td><td>28,508</td><td>16,486</td></tr><tr><td>Total</td><td>-180,392</td><td>160,167</td><td>156,116</td><td>281</td><td>12,144</td><td>149,309</td><td>125,605</td></tr><tr><td>Noncurrent accrued taxes (including</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>unrecognized tax benefits)</td><td>-104,925</td><td>-419,125</td><td>-321,757</td><td>-55,585</td><td>-22,328</td><td>17,256</td><td>-178,447</td></tr><tr><td>Accumulated deferred income</td><td></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>taxes and taxes accrued</td><td>-$1,744,185</td><td>-$1,407,123</td><td>-$1,889,613</td><td>-$661,159</td><td>-$165,198</td><td>-$784,916</td><td>-$625,520</td></tr></table>
<table><tr><td>Federal net operatinglosses</td><td>EntergyArkansas $374 million</td><td>EntergyGulf StatesLouisiana -</td><td>EntergyLouisiana $621 million</td><td>EntergyMississippi -</td><td>EntergyNew Orleans -</td><td>EntergyTexas $197 million</td><td>SystemEnergy $3 million</td></tr><tr><td>Year(s) of expiration</td><td>2028-2031</td><td>N/A</td><td>2029-2031</td><td>N/A</td><td>N/A</td><td>2028-2029</td><td>2031</td></tr><tr><td>State net operating losses</td><td>$28 million</td><td>$207 million</td><td>$975 million</td><td>-</td><td>-</td><td>-</td><td>-</td></tr><tr><td>Year(s) of expiration</td><td>2025</td><td>2023-2024</td><td>2023-2025</td><td>N/A</td><td>N/A</td><td>N/A</td><td>N/A</td></tr><tr><td>Federal minimum taxcredits</td><td>$10 million</td><td>$18 million</td><td>-</td><td>-</td><td>-</td><td>$2 million</td><td>$1 million</td></tr><tr><td>Year(s) of expiration</td><td>never</td><td>never</td><td>N/A</td><td>N/A</td><td>N/A</td><td>never</td><td>never</td></tr><tr><td>Other federal credits</td><td>$2 million</td><td>$1 million</td><td>$1 million</td><td>$1 million</td><td>$1 million</td><td>-</td><td>$1 million</td></tr><tr><td>Year(s) of expiration</td><td>2024-2030</td><td>2024-2030</td><td>2024-2030</td><td>2024-2030</td><td>2024-2030</td><td>N/A</td><td>2024-2030</td></tr><tr><td>State credits</td><td>-</td><td>-</td><td>-</td><td>$8.3 million</td><td>-</td><td>$3.8 million</td><td>$12.8 million</td></tr><tr><td>Year(s) of expiration</td><td>N/A</td><td>N/A</td><td>N/A</td><td>2013-2016</td><td>N/A</td><td>2012-2027</td><td>2015-2016</td></tr></table>
<table><tr><td></td><td colspan="2">2011</td><td colspan="2">2010</td><td colspan="2">2009</td></tr><tr><td></td><td>CommonSharesIssued</td><td>TreasuryShares</td><td>CommonSharesIssued</td><td>TreasuryShares</td><td>CommonSharesIssued</td><td>TreasuryShares</td></tr><tr><td>Beginning Balance, January 1</td><td>254,752,788</td><td>76,006,920</td><td>254,752,788</td><td>65,634,580</td><td>248,174,087</td><td>58,815,518</td></tr><tr><td>Equity Unit Transaction</td><td>-</td><td>-</td><td>-</td><td>-</td><td>6,578,701</td><td>-</td></tr><tr><td>Repurchases</td><td>-</td><td>3,475,000</td><td>-</td><td>11,490,551</td><td>-</td><td>7,680,000</td></tr><tr><td>Issuances:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Employee Stock-BasedCompensation Plans</td><td>-</td><td>-1,079,008</td><td>-</td><td>-1,113,411</td><td>-</td><td>-856,390</td></tr><tr><td>Directors’ Plan</td><td>-</td><td>-5,924</td><td>-</td><td>-4,800</td><td>-</td><td>-4,548</td></tr><tr><td>Ending Balance, December 31</td><td>254,752,788</td><td>78,396,988</td><td>254,752,788</td><td>76,006,920</td><td>254,752,788</td><td>65,634,580</td></tr></table>
<table><tr><td></td><td>Amount (In Millions)</td></tr><tr><td>2010 net revenue</td><td>$5,051</td></tr><tr><td>Mark-to-market tax settlement sharing</td><td>-196</td></tr><tr><td>Purchased power capacity</td><td>-21</td></tr><tr><td>Net wholesale revenue</td><td>-14</td></tr><tr><td>Volume/weather</td><td>13</td></tr><tr><td>ANO decommissioning trust</td><td>24</td></tr><tr><td>Retail electric price</td><td>49</td></tr><tr><td>Other</td><td>-2</td></tr><tr><td>2011 net revenue</td><td>$4,904</td></tr></table>

Question: what is the total amount of variance that favorably affected net revenue in 2011?
Answer: 86
Reasoning program: add(13,24), add(#0,49)