NOTE 13.  BUSINESS SEGMENT INFORMATION (Entergy Corporation, Entergy Arkansas, Entergy Gulf States Louisiana, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, Entergy Texas, and System Energy) Entergy's reportable segments as of December 31, 2008 are Utility and Non-Utility Nuclear.
Utility generates, transmits, distributes, and sells electric power in portions of Arkansas, Louisiana, Mississippi, and Texas, and provides natural gas utility service in portions of Louisiana.
Non-Utility Nuclear owns and operates six nuclear power plants and is primarily focused on selling electric power produced by those plants to wholesale customers.
"All Other" includes the parent company, Entergy Corporation, and other business activity, including the non-nuclear wholesale assets business and earnings on the proceeds of sales of previously-owned businesses.
As a result of the Entergy New Orleans bankruptcy filing, Entergy discontinued the consolidation of Entergy New Orleans retroactive to January 1, 2005, and reported Entergy New Orleans results under the equity method of accounting in the Utility segment in 2006.
On May 7, 2007, the bankruptcy judge entered an order confirming Entergy New Orleans' plan of reorganization.
With confirmation of the plan of reorganization, Entergy reconsolidated Entergy New Orleans in the second quarter 2007, retroactive to January 1, 2007.
Entergy's segment financial information is as follows:
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Utility
## Table 1 ##
System Energy Resources, Inc.  Management's Financial Discussion and Analysis 384 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:
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(1) It is expected that additional financing under the lease will be arranged as needed to acquire additional fuel, to pay interest, and to pay maturing debt.
If such additional financing cannot be arranged, however, System Energy must repurchase sufficient nuclear fuel to allow the lessor to meet its obligations.
(2) Purchase obligations represent the minimum purchase obligation or cancellation charge for contractual obligations to purchase goods or services.
For System Energy, it includes nuclear fuel purchase obligations.
In addition to the contractual obligations given above, System Energy expects to contribute $5.8 million to its pension plans and $3.0 million to its other postretirement plans in 2009.
Guidance pursuant to the Pension Protection Act of 2006 rules, effective for the 2008 plan year and beyond, may affect the level of System Energy's pension contributions in the future.
Also in addition to the contractual obligations, System Energy has $172.2 million of unrecognized tax benefits and interest for which the timing of payments beyond 12 months cannot be reasonably estimated due to uncertainties in the timing of effective settlement of tax positions.
See Note 3 to the financial statements for additional information regarding unrecognized tax benefits.
The planned capital investment estimate for System Energy reflects capital required to support the existing business of System Energy and for a potential approximately 178 MW uprate of the Grand Gulf nuclear plant that is currently estimated to cost System Energy $247 million for the 2009-2011 period.
The planned construction and capital investment amounts given above also include initial development costs for potential new nuclear development at the Grand Gulf and River Bend sites, including licensing and design activities.
This project is in the early stages, and several issues remain to be addressed over time before significant additional capital would be committed to this project.
In addition, Entergy is temporarily suspending reviews of the two license applications for the sites and will explore alternative nuclear technologies for this project.
As of December 31, 2008, $95.6 million in construction work in progress is recorded on System Energy's balance sheet related to this project.
Entergy's Utility supply plan initiative will continue to seek to transform its generation portfolio with new or repowered generation resources.
Opportunities resulting from the supply plan initiative, including new projects or the exploration of alternative financing sources, could result in increases or decreases in the capital expenditure estimates given above.
As a wholly-owned subsidiary, System Energy dividends its earnings to Entergy Corporation at a percentage determined monthly.
Currently, all of System Energy's retained earnings are available for distribution.
Sources of Capital System Energy's sources to meet its capital requirements include: x internally generated funds; x cash on hand; x debt issuances; and x bank financing under new or existing facilities.
System Energy had three-year letters of credit in place that were scheduled to expire in March 2003 securing certain of its obligations related to the sale-leaseback of a portion of Grand Gulf.
System Energy replaced the letters of credit before their expiration with new three-year letters of credit totaling approximately $198 million that were backed by cash collateral.
In December 2003, System Energy replaced the cash-backed letters of credit
Entergy Corporation and Subsidiaries Management's Financial Discussion and Analysis
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(1) A sale of power on a unit-contingent basis coupled with a guarantee of availability provides for the payment to the power purchaser of contract damages, if incurred, in the event the seller fails to deliver power as a result of the failure of the specified generation unit to generate power at or above a specified availability threshold.
All of Entergy's outstanding guarantees of availability provide for dollar limits on Entergy's maximum liability under such guarantees.
(2) The Vermont Yankee acquisition included a 10-year PPA under which the former owners will buy most of the power produced by the plant, which is through the expiration in 2012 of the current operating license for the plant.
The PPA includes an adjustment clause under which the prices specified in the PPA will be adjusted downward monthly, beginning in November 2005, if power market prices drop below PPA prices, which has not happened thus far and is not expected in the foreseeable future.
Entergy's Non-Utility Nuclear business' purchase of the FitzPatrick and Indian Point 3 plants from NYPA included value sharing agreements with NYPA.
In October 2007, NYPA and the subsidiaries that own the FitzPatrick and Indian Point 3 plants amended and restated the value sharing agreements to clarify and amend certain provisions of the original terms.
Under the amended value sharing agreements, Entergy's Non-Utility Nuclear business agreed to make annual payments to NYPA based on the generation output of the Indian Point 3 and FitzPatrick plants from January 2007 through December 2014.
Entergy's Non-Utility Nuclear business will pay NYPA $6.59 per MWh for power sold from Indian Point 3, up to an annual cap of $48 million, and $3.91 per MWh for power sold from FitzPatrick, up to an annual cap of $24 million.
The annual payment for each year is due by January 15 of the following year.
In August 2008, Non-Utility Nuclear entered into a resolution of a dispute with NYPA over the applicability of the value sharing agreements to its FitzPatrick and Indian Point 3 nuclear power plants after the planned spin-off of the Non-Utility Nuclear business.
Under the resolution, Non-Utility Nuclear agreed not to treat the separation as a "Cessation Event" that would terminate its obligation to make the payments under the value sharing agreements.
As a result, after the spin-off transaction, Non-Utility Nuclear will continue to be obligated to make payments to NYPA under the amended and restated value sharing agreements.
Non-Utility Nuclear will record its liability for payments to NYPA as power is generated and sold by Indian Point 3 and FitzPatrick.
Non-Utility Nuclear recorded a $72 million liability for generation in both 2008 and 2007.
An amount equal to the liability will be recorded to the plant asset account as contingent purchase price consideration for the plants.
This amount will be depreciated over the expected remaining useful life of the plants.
Some of the agreements to sell the power produced by Entergy's Non-Utility Nuclear power plants contain provisions that require an Entergy subsidiary to provide collateral to secure its obligations under the agreements.
The Entergy subsidiary is required to provide collateral based upon the difference between the current market and contracted power prices in the regions where Non-Utility Nuclear sells power.
The primary form of collateral to satisfy these requirements is an Entergy Corporation guaranty.
Cash and letters of credit are also acceptable forms of collateral.
At December 31, 2008, based on power prices at that time, Entergy had in place as collateral $536 million of Entergy Corporation guarantees for wholesale transactions, including $60 million of guarantees that support letters of credit and $2 million of cash collateral.
As of December 31, 2008, the assurance requirement associated with Non-Utility Nuclear is estimated to increase by an amount of up to $216 million if gas prices increase $1 per MMBtu in both the short- and long-term markets.
In the event of a decrease in Entergy Corporation's credit rating to below investment grade, based on power prices as of December 31, 2008, Entergy would have been required
Entergy Corporation and Subsidiaries Management’s Financial Discussion and Analysis 4 combination.
Consistent with the terms of the stipulated settlement in the business combination proceeding, electric customers of Entergy Louisiana will realize customer credits associated with the business combination; accordingly, in October 2015, Entergy recorded a regulatory liability of $107 million ($66 million net-of-tax).
These costs are being amortized over a nine-year period beginning December 2015.
See Note 2 to the financial statements for further discussion of the business combination and customer credits.
The volume/weather variance is primarily due to the effect of more favorable weather during the unbilled period and an increase in industrial usage, partially offset by the effect of less favorable weather on residential sales.
The increase in industrial usage is primarily due to expansion projects, primarily in the chemicals industry, and increased demand from new customers, primarily in the industrial gases industry.
The Louisiana Act 55 financing savings obligation variance results from a regulatory charge for tax savings to be shared with customers per an agreement approved by the LPSC.
The tax savings results from the 2010-2011 IRS audit settlement on the treatment of the Louisiana Act 55 financing of storm costs for Hurricane Gustav and Hurricane Ike.
See Note 3 to the financial statements for additional discussion of the settlement and benefit sharing.
Included in Other is a provision of $23 million recorded in 2016 related to the settlement of the Waterford 3 replacement steam generator prudence review proceeding, offset by a provision of $32 million recorded in 2015 related to the uncertainty at that time associated with the resolution of the Waterford 3 replacement steam generator prudence review proceeding.
See Note 2 to the financial statements for a discussion of the Waterford 3 replacement steam generator prudence review proceeding.
Entergy Wholesale Commodities Following is an analysis of the change in net revenue comparing 2016 to 2015.

<table><tr><td>  2008</td><td>  Utility</td><td> Non-Utility Nuclear*</td><td>  All Other*</td><td>  Eliminations</td><td>  Consolidated</td></tr><tr><td> </td><td colspan="5">(In Thousands)</td></tr><tr><td>Operating revenues</td><td>$10,318,630</td><td>$2,558,378</td><td>$241,715</td><td>-$24,967</td><td>$13,093,756</td></tr><tr><td>Deprec., amort. & decomm.</td><td>$984,651</td><td>$220,128</td><td>$15,490</td><td>$-</td><td>$1,220,269</td></tr><tr><td>Interest and dividend income</td><td>$122,657</td><td>$62,473</td><td>$116,830</td><td>-$153,744</td><td>$148,216</td></tr><tr><td>Equity in loss of unconsolidated equity affiliates</td><td>-$3</td><td>$-</td><td>-$11,681</td><td>$-</td><td>-$11,684</td></tr><tr><td>Interest and other charges</td><td>$442,523</td><td>$53,926</td><td>$286,185</td><td>-$153,744</td><td>$628,890</td></tr><tr><td>Income taxes (benefits)</td><td>$371,281</td><td>$319,107</td><td>-$87,390</td><td>$-</td><td>$602,998</td></tr><tr><td>Net income (loss)</td><td>$587,837</td><td>$797,280</td><td>-$164,551</td><td>$-</td><td>$1,220,566</td></tr><tr><td>Total assets</td><td>$28,810,147</td><td>$7,848,195</td><td>$2,586,456</td><td>-$2,627,980</td><td>$36,616,818</td></tr><tr><td>Investment in affiliates - at equity</td><td>$199</td><td>$-</td><td>$66,048</td><td>$-</td><td>$66,247</td></tr><tr><td>Cash paid for long-lived asset additions</td><td>$1,921,624</td><td>$271,901</td><td>$18,730</td><td>$-</td><td>$2,212,255</td></tr></table>
<table><tr><td>  2007</td><td>  Utility</td><td> Non-Utility Nuclear*</td><td>  All Other*</td><td>  Eliminations</td><td>  Consolidated</td></tr><tr><td> </td><td colspan="5">(In Thousands)</td></tr><tr><td>Operating revenues</td><td>$9,255,075</td><td>$2,029,666</td><td>$225,216</td><td>-$25,559</td><td>$11,484,398</td></tr><tr><td>Deprec., amort. & decomm.</td><td>$939,152</td><td>$177,872</td><td>$14,586</td><td>$-</td><td>$1,131,610</td></tr><tr><td>Interest and dividend income</td><td>$124,992</td><td>$102,840</td><td>$88,066</td><td>-$81,901</td><td>$233,997</td></tr><tr><td>Equity in earnings of unconsolidated equity affiliates</td><td> -$2</td><td> $-</td><td> $3,178</td><td> $-</td><td> $3,176</td></tr><tr><td>Interest and other charges</td><td>$444,067</td><td>$34,738</td><td>$265,253</td><td>-$81,901</td><td>$662,157</td></tr><tr><td>Income taxes (benefits)</td><td>$382,025</td><td>$230,407</td><td>-$98,015</td><td>$-</td><td>$514,417</td></tr><tr><td>Net income (loss)</td><td>$682,707</td><td>$539,200</td><td>-$87,058</td><td>$-</td><td>$1,134,849</td></tr><tr><td>Total assets</td><td>$26,174,159</td><td>$7,014,484</td><td>$1,982,429</td><td>-$1,528,070</td><td>$33,643,002</td></tr><tr><td>Investment in affiliates - at equity</td><td>$202</td><td>$-</td><td>$78,790</td><td>$-</td><td>$78,992</td></tr><tr><td>Cash paid for long-lived asset additions</td><td> $1,315,564</td><td> $258,457</td><td> $2,754</td><td> $1,255</td><td> $1,578,030</td></tr></table>
<table><tr><td></td><td> 2009</td><td> 2010-2011</td><td> 2012-2013</td><td> After 2013</td><td> Total</td></tr><tr><td></td><td colspan="5">(In Millions)</td></tr><tr><td>Planned construction and</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>capital investment</td><td>$135</td><td>$275</td><td>N/A</td><td>N/A</td><td>$410</td></tr><tr><td>Long-term debt</td><td>$76</td><td>$155</td><td>$222</td><td>$736</td><td>$1,189</td></tr><tr><td>Nuclear fuel lease obligations -1</td><td>$38</td><td>$88</td><td>N/A</td><td>N/A</td><td>$126</td></tr><tr><td>Purchase obligations -2</td><td>$-</td><td>$17</td><td>$20</td><td>$66</td><td>$103</td></tr></table>
<table><tr><td></td><td> 2009</td><td> 2010</td><td> 2011</td><td> 2012</td><td> 2013</td></tr><tr><td> Non-Utility Nuclear:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Percent of planned generation sold forward:</td><td></td><td></td><td></td><td></td><td></td></tr><tr><td>Unit-contingent</td><td>48%</td><td>31%</td><td>29%</td><td>18%</td><td>12%</td></tr><tr><td>Unit-contingent with guarantee of availability -1</td><td>38%</td><td>35%</td><td>17%</td><td>7%</td><td>6%</td></tr><tr><td>Total</td><td>86%</td><td>66%</td><td>46%</td><td>25%</td><td>18%</td></tr><tr><td>Planned generation (TWh)</td><td>41</td><td>40</td><td>41</td><td>41</td><td>40</td></tr><tr><td>Average contracted price per MWh -2</td><td>$61</td><td>$60</td><td>$56</td><td>$54</td><td>$50</td></tr></table>

Question: What is the ratio of Utility's Operating revenues to the total in 2007?
Answer: 0.40294