Part I Item 1 Entergy Corporation, Utility operating companies, and System Energy 202 Entergy New Orleans provides electric and gas service in the City of New Orleans pursuant to indeterminate permits set forth in city ordinances (except electric service in Algiers, which is provided by Entergy Louisiana).
These ordinances contain a continuing option for the City of New Orleans to purchase Entergy New Orleans’s electric and gas utility properties.
Entergy Texas holds a certificate of convenience and necessity from the PUCT to provide electric service to areas within approximately 27 counties in eastern Texas, and holds non-exclusive franchises to provide electric service in approximately 68 incorporated municipalities.
Entergy Texas was typically granted 50-year franchises, but recently has been receiving 25-year franchises.
Entergy Texas’s electric franchises expire during 2013-2058.
The business of System Energy is limited to wholesale power sales.
It has no distribution franchises.
Property and Other Generation Resources Generating Stations The total capability of the generating stations owned and leased by the Utility operating companies and System Energy as of December 31, 2011, is indicated below:
## Table 0 ##
(1) “Owned and Leased Capability” is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel (assuming no curtailments) that each station was designed to utilize.
The Entergy System's load and capacity projections are reviewed periodically to assess the need and timing for additional generating capacity and interconnections.
These reviews consider existing and projected demand, the availability and price of power, the location of new load, and the economy.
Summer peak load in the Entergy System service territory has averaged 21,246 MW from 2002-2011.
In the 2002 time period, the Entergy System's long-term capacity resources, allowing for an adequate reserve margin, were approximately 3,000 MW less than the total capacity required for peak period demands.
In this time period the Entergy System met its capacity shortages almost entirely through short-term power purchases in the wholesale spot market.
In the fall of 2002, the Entergy System began a program to add new resources to its existing generation portfolio and began a process of issuing requests for proposals (RFP) to procure supply-side resources from sources other than the spot market to meet the unique regional needs of the Utility operating companies.
The Entergy System has adopted a long-term resource strategy that calls for the bulk of capacity needs to be met through long-term resources, whether owned or contracted.
Entergy refers to this strategy as the "Portfolio Transformation Strategy".
Over the past nine years, Portfolio Transformation has resulted in the addition of about 4,500 MW of new long-term resources.
These figures do not include transactions currently pending as a result of the Summer 2009 RFP.
When the Summer 2009 RFP transactions are included in the Entergy System portfolio of long-term resources and adjusting for unit deactivations of older generation, the Entergy System is approximately 500 MW short of its projected 2012 peak load plus reserve margin.
This remaining need is expected to be met through a nuclear uprate at Grand Gulf and limited-term resources.
The Entergy System will continue to access the spot power market to economically
Uncertain Tax Positions As of May 31, 2013, we had $316.8 million of gross uncertain tax positions.
If recognized, approximately $106.4 million of that amount would affect our effective tax rate in future periods.
We recorded a gross decrease of $187.7 million associated with our nonU.
S.  subsidiaries due to the resolution of certain tax matters, of which $179.3 million impacted our effective tax rate.
It is reasonably possible that the amount of gross unrecognized tax benefits will decrease in the next twelve months by approximately $30 million associated with our non-U.
S.  subsidiaries due to the expected resolution of a treaty-based process.
The difference between the resolution’s outcome and what we have recorded as an unrecognized tax benefit may result in an expense; however, an estimate of the impact to the effective tax rate cannot reasonably be made.
It is expected that there will be additional changes to the amount of uncertain tax positions in the next twelve months; however, additional changes cannot reasonably be estimated.
## Table 1 ##
We recognize interest and penalties related to unrecognized tax benefits as a component of our income tax expense.
Interest and penalties accrued in our Consolidated Balance Sheets as of May 31, 2013 and May 31, 2012 are $53.8 million and $52.0 million, respectively, and are included in other noncurrent liabilities in the Consolidated Balance Sheets.
We operate in multiple tax jurisdictions, both within the United States and outside the United States, and face audits from various tax authorities regarding transfer pricing, deductibility of certain expenses, and intercompany transactions, as well as other matters.
With few exceptions, we are no longer subject to examination for tax years prior to 2001.
We are currently under audit by the U. S.  Internal Revenue Service for fiscal 2011 and 2012 and by the Canada Revenue Agency for fiscal 2001 to 2011.
Based on the information available, we do not anticipate significant changes to our unrecognized tax benefits as a result of these examinations.
The Company has entered into a tax treaty-based process to resolve certain multi-jurisdictional uncertain income tax matters.
An unfavorable resolution of those matters could impact our ability to utilize our foreign tax credit carryforward and affect the amount of undistributed earnings of non-U.
S.  subsidiaries for which we have not recognized a deferred tax liability.
During the second quarter of fiscal 2013, the Internal Revenue Service concluded its audit for fiscal 2009 and 2010.14.
ACCOUNTING FOR ASSET RETIREMENT OBLIGATIONS We recognize AROs in the period in which we have an existing legal obligation associated with the retirement of a tangible long-lived asset, and the amount of the liability can be reasonably estimated.
The ARO is recognized at fair value when the liability is incurred with a corresponding increase in the carrying amount of the related long lived asset.
We depreciate the tangible asset over its estimated useful life.
Our legal obligations related to asset retirement require us to: (i) reclaim lands disturbed by mining as a condition to receive permits to mine phosphate ore reserves; (ii) treat low pH process water in phosphogypsum management systems (the “Gypstacks”) to neutralize acidity; (iii) close and monitor Gypstacks at our Florida and Louisiana facilities at the end of their useful lives; (iv) remediate certain other conditional obligations; (v) remove all surface structures and equipment, plug and abandon mine shafts, contour and revegetate, as necessary, and monitor for five years after closing our Carlsbad, New Mexico facility and (vi) decommission facilities, manage tailings and execute site reclamation at our Saskatchewan potash mines at the end of their useful lives.
The estimated liability for these legal obligations is based on the estimated cost to satisfy the above obligations which is discounted using a credit-adjusted risk-free rate.
Accounting for Pension and Postretirement Plans The year-end status of the North American plans was as follows:
## Table 2 ##
The accumulated benefit obligation for the defined benefit pension plans was $782.5 million and $736.2 million as of May 31, 2013 and 2012, respectively.
The components of net annual periodic benefit costs and other amounts recognized in other comprehensive income include the following components:
## Table 3 ##
SCHEDULE II.
VALUATION AND QUALIFYING ACCOUNTS For the Years ended May 31, 2013, 2012, and 2011 In millions

<table><tr><td></td><td>Owned and Leased Capability MW-1</td></tr><tr><td>Company</td><td>Total</td><td>Gas/Oil</td><td>Nuclear</td><td>Coal</td><td>Hydro</td></tr><tr><td>Entergy Arkansas</td><td>4,774</td><td>1,668</td><td>1,823</td><td>1,209</td><td>74</td></tr><tr><td>Entergy Gulf States Louisiana</td><td>3,317</td><td>1,980</td><td>974</td><td>363</td><td>-</td></tr><tr><td>Entergy Louisiana</td><td>5,424</td><td>4,265</td><td>1,159</td><td>-</td><td>-</td></tr><tr><td>Entergy Mississippi</td><td>3,229</td><td>2,809</td><td>-</td><td>420</td><td>-</td></tr><tr><td>Entergy New Orleans</td><td>764</td><td>764</td><td>-</td><td>-</td><td>-</td></tr><tr><td>Entergy Texas</td><td>2,538</td><td>2,269</td><td>-</td><td>269</td><td>-</td></tr><tr><td>System Energy</td><td>1,071</td><td>-</td><td>1,071</td><td>-</td><td>-</td></tr><tr><td>Total</td><td>21,117</td><td>13,755</td><td>5,027</td><td>2,261</td><td>74</td></tr></table>
<table><tr><td></td><td colspan="2">May 31,</td></tr><tr><td><i>(in millions)</i></td><td>2013</td><td>2012</td></tr><tr><td>Gross unrecognized tax benefits, beginning of year</td><td>$476.9</td><td>$263.5</td></tr><tr><td>Gross increases:</td><td></td><td></td></tr><tr><td>Prior year tax positions</td><td>7.7</td><td>103.1</td></tr><tr><td>Current year tax positions</td><td>36.6</td><td>146.9</td></tr><tr><td>Gross decreases:</td><td></td><td></td></tr><tr><td>Prior year tax positions</td><td>-204.3</td><td>-34.8</td></tr><tr><td>Currency translation</td><td>-0.1</td><td>-1.8</td></tr><tr><td>Gross unrecognized tax benefits, end of year</td><td>$316.8</td><td>$476.9</td></tr></table>
<table><tr><td></td><td colspan="2">Pension Plans</td><td colspan="2">Postretirement Benefit Plans</td></tr><tr><td><i>(in millions)</i></td><td>2013</td><td>2012</td><td>2013</td><td>2012</td></tr><tr><td>Change in projected benefit obligation:</td><td></td><td></td><td></td><td></td></tr><tr><td>Benefit obligation at beginning of year</td><td>$743.3</td><td>$694.3</td><td>$59.9</td><td>$60.1</td></tr><tr><td>Service cost</td><td>6.5</td><td>5.6</td><td>0.6</td><td>0.3</td></tr><tr><td>Interest cost</td><td>32.6</td><td>34.5</td><td>2.3</td><td>2.6</td></tr><tr><td>Plan amendments</td><td>15.3</td><td>-</td><td>-</td><td>-</td></tr><tr><td>Actuarial loss</td><td>26.9</td><td>59.3</td><td>0.6</td><td>4.0</td></tr><tr><td>Currency fluctuations</td><td>-0.4</td><td>-15.5</td><td>-</td><td>-0.9</td></tr><tr><td>Employee contribution</td><td>-</td><td>-</td><td>0.1</td><td>0.1</td></tr><tr><td>Benefits paid</td><td>-35.6</td><td>-34.9</td><td>-5.6</td><td>-6.3</td></tr><tr><td>Projected benefit obligation at end of year</td><td>$788.6</td><td>$743.3</td><td>$57.9</td><td>$59.9</td></tr><tr><td>Change in plan assets:</td><td></td><td></td><td></td><td></td></tr><tr><td>Fair value at beginning of year</td><td>$654.4</td><td>$630.0</td><td>$-</td><td>$-</td></tr><tr><td>Currency fluctuations</td><td>-0.3</td><td>-12.9</td><td>-</td><td>-</td></tr><tr><td>Actual return</td><td>53.9</td><td>45.4</td><td>-</td><td>-</td></tr><tr><td>Company contribution</td><td>35.2</td><td>26.8</td><td>5.5</td><td>6.2</td></tr><tr><td>Employee contribution</td><td>-</td><td>-</td><td>0.1</td><td>0.1</td></tr><tr><td>Benefits paid</td><td>-35.6</td><td>-34.9</td><td>-5.6</td><td>-6.3</td></tr><tr><td>Fair value at end of year</td><td>$707.6</td><td>$654.4</td><td>$-</td><td>$-</td></tr><tr><td>Funded status of the plans as of May 31</td><td>$-81.0</td><td>$-88.9</td><td>$-57.9</td><td>$-59.9</td></tr><tr><td>Amounts recognized in the consolidated balance sheets:</td><td></td><td></td><td></td><td></td></tr><tr><td>Noncurrent assets</td><td>$6.4</td><td>$-</td><td>$-</td><td>$-</td></tr><tr><td>Current liabilities</td><td>-0.6</td><td>-0.6</td><td>-5.9</td><td>-6.3</td></tr><tr><td>Noncurrent liabilities</td><td>-86.8</td><td>-88.3</td><td>-52.0</td><td>-53.6</td></tr><tr><td>Amounts recognized in accumulated other comprehensive (income) loss</td><td></td><td></td><td></td><td></td></tr><tr><td>Prior service costs (credits)</td><td>$27.1</td><td>$13.2</td><td>$-3.2</td><td>$-4.9</td></tr><tr><td>Actuarial (gain)/loss</td><td>125.4</td><td>131.3</td><td>-7.0</td><td>-8.9</td></tr></table>
<table><tr><td><i>(in millions)</i></td><td colspan="3">Pension Plans</td><td colspan="3">Postretirement Benefit Plans</td></tr><tr><td>  <i>Net Periodic Benefit Cost</i> </td><td>2013</td><td>2012</td><td>2011</td><td>2013</td><td>2012</td><td>2011</td></tr><tr><td>Service cost</td><td>$6.5</td><td>$5.6</td><td>$5.0</td><td>$0.6</td><td>$0.3</td><td>$0.4</td></tr><tr><td>Interest cost</td><td>32.6</td><td>34.5</td><td>36.2</td><td>2.3</td><td>2.6</td><td>3.1</td></tr><tr><td>Expected return on plan assets</td><td>-37.3</td><td>-35.8</td><td>-38.0</td><td>-</td><td>-</td><td>-</td></tr><tr><td>Amortization of:</td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Prior service cost/(credit)</td><td>1.3</td><td>1.3</td><td>0.9</td><td>-1.7</td><td>-1.7</td><td>-2.3</td></tr><tr><td>Actuarial (gain)/loss</td><td>16.1</td><td>13.4</td><td>7.4</td><td>-1.3</td><td>-1.8</td><td>-0.7</td></tr><tr><td>Net periodic benefit (income) cost</td><td>$19.2</td><td>$19.0</td><td>$11.5</td><td>$-0.1</td><td>$-0.6</td><td>$0.5</td></tr><tr><td> <i>Other Changes in Plan Assets and Benefit</i></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td> <i>Obligations Recognized in Other</i></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td> <i>Comprehensive Income</i></td><td></td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Prior service cost (credit) recognized in other comprehensive income</td><td>$14.1</td><td>$-1.3</td><td>$4.9</td><td>$1.7</td><td>$1.7</td><td>$2.3</td></tr><tr><td>Net actuarial loss (gain) recognized in other comprehensive income</td><td>-5.9</td><td>36.3</td><td>-26.7</td><td>1.9</td><td>5.8</td><td>-38.0</td></tr><tr><td>Total recognized in other comprehensive income</td><td>$8.2</td><td>$35.0</td><td>$-21.8</td><td>$3.6</td><td>$7.5</td><td>$-35.7</td></tr><tr><td>Total recognized in net periodic benefit (income) cost and other comprehensive income</td><td>$27.4</td><td>$54.0</td><td>$-10.3</td><td>$3.5</td><td>$6.9</td><td>$-35.2</td></tr></table>

Question: What is the sum of the Fair value at beginning of year in the years where Service cost is positive? (in million)
Answer: 1284.4