whpthomas/finqa-parquet huggingface dataset:
entergy corporation and subsidiaries notes to financial statements amount ( in millions ) .
what percentage of total acquired assets is related to plant acquisition?
subsequent to the closing , entergy received approximately $ 6 million from consumers energy company as part of the post-closing adjustment defined in the asset sale agreement . the post-closing adjustment amount resulted in an approximately $ 6 million reduction in plant and a corresponding reduction in other liabilities . for the ppa , which was at below-market prices at the time of the acquisition , non-utility nuclear will amortize a liability to revenue over the life of the agreement . the amount that will be amortized each period is based upon the difference between the present value calculated at the date of acquisition of each year's difference between revenue under the agreement and revenue based on estimated market prices . amounts amortized to revenue were $ 53 million in 2009 , $ 76 million in 2008 , and $ 50 million in 2007 . the amounts to be amortized to revenue for the next five years will be $ 46 million for 2010 , $ 43 million for 2011 , $ 17 million in 2012 , $ 18 million for 2013 , and $ 16 million for 2014 . nypa value sharing agreements non-utility nuclear's purchase of the fitzpatrick and indian point 3 plants from nypa included value sharing agreements with nypa . in october 2007 , non-utility nuclear and nypa amended and restated the value sharing agreements to clarify and amend certain provisions of the original terms . under the amended value sharing agreements , non-utility nuclear will make annual payments to nypa based on the generation output of the indian point 3 and fitzpatrick plants from january 2007 through december 2014 . non-utility nuclear 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's output is due by january 15 of the following year . non-utility nuclear will record its liability for payments to nypa as power is generated and sold by indian point 3 and fitzpatrick . an amount equal to the liability will be recorded to the plant asset account as contingent purchase price consideration for the plants . in 2009 , 2008 , and 2007 , non-utility nuclear recorded $ 72 million as plant for generation during each of those years . this amount will be depreciated over the expected remaining useful life of the plants . 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 , enexus will continue to be obligated to make payments to nypa under the amended and restated value sharing agreements. .
entergy corporation and subsidiaries notes to financial statements equitable discretion and not require refunds for the 20-month period from september 13 , 2001 - may 2 , 2003 . because the ruling on refunds relied on findings in the interruptible load proceeding , which is discussed in a separate section below , the ferc concluded that the refund ruling will be held in abeyance pending the outcome of the rehearing requests in that proceeding . on the second issue , the ferc reversed its prior decision and ordered that the prospective bandwidth remedy begin on june 1 , 2005 ( the date of its initial order in the proceeding ) rather than january 1 , 2006 , as it had previously ordered . pursuant to the october 2011 order , entergy was required to calculate the additional bandwidth payments for the period june - december 2005 utilizing the bandwidth formula tariff prescribed by the ferc that was filed in a december 2006 compliance filing and accepted by the ferc in an april 2007 order . as is the case with bandwidth remedy payments , these payments and receipts will ultimately be paid by utility operating company customers to other utility operating company customers . in december 2011 , entergy filed with the ferc its compliance filing that provides the payments and receipts among the utility operating companies pursuant to the ferc 2019s october 2011 order . the filing shows the following payments/receipts among the utility operating companies : payments ( receipts ) ( in millions ) .
what portion of the entergy arkansas payment goes to entergy mississippi?
entergy arkansas made its payment in january 2012 . in february 2012 , entergy arkansas filed for an interim adjustment to its production cost allocation rider requesting that the $ 156 million payment be collected from customers over the 22-month period from march 2012 through december 2013 . in march 2012 the apsc issued an order stating that the payment can be recovered from retail customers through the production cost allocation rider , subject to refund . the lpsc and the apsc have requested rehearing of the ferc 2019s october 2011 order . in december 2013 the lpsc filed a petition for a writ of mandamus at the united states court of appeals for the d.c . circuit . in its petition , the lpsc requested that the d.c . circuit issue an order compelling the ferc to issue a final order on pending rehearing requests . in its response to the lpsc petition , the ferc committed to rule on the pending rehearing request before the end of february . in january 2014 the d.c . circuit denied the lpsc's petition . the apsc , the lpsc , the puct , and other parties intervened in the december 2011 compliance filing proceeding , and the apsc and the lpsc also filed protests . calendar year 2013 production costs the liabilities and assets for the preliminary estimate of the payments and receipts required to implement the ferc 2019s remedy based on calendar year 2013 production costs were recorded in december 2013 , based on certain year-to-date information . the preliminary estimate was recorded based on the following estimate of the payments/receipts among the utility operating companies for 2014. .
entergy mississippi , inc . management's financial discussion and analysis sources of capital entergy mississippi's sources to meet its capital requirements include : internally generated funds ; cash on hand ; debt or preferred stock issuances ; and bank financing under new or existing facilities . entergy mississippi may refinance or redeem debt and preferred stock prior to maturity , to the extent market conditions and interest and dividend rates are favorable . all debt and common and preferred stock issuances by entergy mississippi require prior regulatory approval . preferred stock and debt issuances are also subject to issuance tests set forth in its corporate charter , bond indenture , and other agreements . entergy mississippi has sufficient capacity under these tests to meet its foreseeable capital needs . entergy mississippi has two separate credit facilities in the aggregate amount of $ 50 million and renewed both facilities through may 2009 . borrowings under the credit facilities may be secured by a security interest in entergy mississippi's accounts receivable . no borrowings were outstanding under either credit facility as of december 31 , 2008 . entergy mississippi has obtained short-term borrowing authorization from the ferc under which it may borrow through march 31 , 2010 , up to the aggregate amount , at any one time outstanding , of $ 175 million . see note 4 to the financial statements for further discussion of entergy mississippi's short-term borrowing limits . entergy mississippi has also obtained an order from the ferc authorizing long-term securities issuances . the current long-term authorization extends through june 30 , 2009 . entergy mississippi's receivables from or ( payables to ) the money pool were as follows as of december 31 for each of the following years: .
how is the cash flow of entergy mississippi affected by the balance in money pool from 2006 to 2007?
in may 2007 , $ 6.6 million of entergy mississippi's receivable from the money pool was replaced by a note receivable from entergy new orleans . see note 4 to the financial statements for a description of the money pool . state and local rate regulation the rates that entergy mississippi charges for electricity significantly influence its financial position , results of operations , and liquidity . entergy mississippi is regulated and the rates charged to its customers are determined in regulatory proceedings . a governmental agency , the mpsc , is primarily responsible for approval of the rates charged to customers . formula rate plan in march 2008 , entergy mississippi made its annual scheduled formula rate plan filing for the 2007 test year with the mpsc . the filing showed that a $ 10.1 million increase in annual electric revenues is warranted . in june 2008 , entergy mississippi reached a settlement with the mississippi public utilities staff that would result in a $ 3.8 million rate increase . in january 2009 the mpsc rejected the settlement and left the current rates in effect . entergy mississippi appealed the mpsc's decision to the mississippi supreme court. .
shareholder return performance presentation the graph presented below compares the cumulative total shareholder return on state street's common stock to the cumulative total return of the s&p 500 index and the s&p financial index over a five-year period . the cumulative total shareholder return assumes the investment of $ 100 in state street common stock and in each index on december 31 , 2007 at the closing price on the last trading day of 2007 , and also assumes reinvestment of common stock dividends . the s&p financial index is a publicly available measure of 80 of the standard & poor's 500 companies , representing 26 diversified financial services companies , 22 insurance companies , 17 real estate companies and 15 banking companies . comparison of five-year cumulative total shareholder return .
what is the percent change in state street corporation's cumulative total shareholder return on common stock between 2008 and 2009?
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table of contents the foreign provision for income taxes is based on foreign pre-tax earnings of $ 33.6 billion , $ 30.5 billion and $ 36.8 billion in 2014 , 2013 and 2012 , respectively . the company 2019s consolidated financial statements provide for any related tax liability on undistributed earnings that the company does not intend to be indefinitely reinvested outside the u.s . substantially all of the company 2019s undistributed international earnings intended to be indefinitely reinvested in operations outside the u.s . were generated by subsidiaries organized in ireland , which has a statutory tax rate of 12.5% ( 12.5 % ) . as of september 27 , 2014 , u.s . income taxes have not been provided on a cumulative total of $ 69.7 billion of such earnings . the amount of unrecognized deferred tax liability related to these temporary differences is estimated to be approximately $ 23.3 billion . as of september 27 , 2014 and september 28 , 2013 , $ 137.1 billion and $ 111.3 billion , respectively , of the company 2019s cash , cash equivalents and marketable securities were held by foreign subsidiaries and are generally based in u.s . dollar-denominated holdings . amounts held by foreign subsidiaries are generally subject to u.s . income taxation on repatriation to the u.s . a reconciliation of the provision for income taxes , with the amount computed by applying the statutory federal income tax rate ( 35% ( 35 % ) in 2014 , 2013 and 2012 ) to income before provision for income taxes for 2014 , 2013 and 2012 , is as follows ( dollars in millions ) : the company 2019s income taxes payable have been reduced by the tax benefits from employee stock plan awards . for stock options , the company receives an income tax benefit calculated as the tax effect of the difference between the fair market value of the stock issued at the time of the exercise and the exercise price . for rsus , the company receives an income tax benefit upon the award 2019s vesting equal to the tax effect of the underlying stock 2019s fair market value . the company had net excess tax benefits from equity awards of $ 706 million , $ 643 million and $ 1.4 billion in 2014 , 2013 and 2012 , respectively , which were reflected as increases to common stock . apple inc . | 2014 form 10-k | 64 .
what was the highest effective tax rate , as a percentage?
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remitted to the u.s . due to foreign tax credits and exclusions that may become available at the time of remittance . at december 31 , 2010 , aon had domestic federal operating loss carryforwards of $ 56 million that will expire at various dates from 2011 to 2024 , state operating loss carryforwards of $ 610 million that will expire at various dates from 2011 to 2031 , and foreign operating and capital loss carryforwards of $ 720 million and $ 251 million , respectively , nearly all of which are subject to indefinite carryforward . unrecognized tax provisions the following is a reconciliation of the company 2019s beginning and ending amount of unrecognized tax benefits ( in millions ) : .
what was the average accrued interest by aon from 2009 to 2010 in millions
as of december 31 , 2010 , $ 85 million of unrecognized tax benefits would impact the effective tax rate if recognized . aon does not expect the unrecognized tax positions to change significantly over the next twelve months , except for a potential reduction of unrecognized tax benefits in the range of $ 10-$ 15 million relating to anticipated audit settlements . the company recognizes penalties and interest related to unrecognized income tax benefits in its provision for income taxes . aon accrued potential penalties of less than $ 1 million during each of 2010 , 2009 and 2008 . aon accrued interest of less than $ 1 million in 2010 , $ 2 million during 2009 and less than $ 1 million in 2008 . aon has recorded a liability for penalties of $ 5 million and for interest of $ 18 million for both december 31 , 2010 and 2009 . aon and its subsidiaries file income tax returns in the u.s . federal jurisdiction as well as various state and international jurisdictions . aon has substantially concluded all u.s . federal income tax matters for years through 2006 . material u.s . state and local income tax jurisdiction examinations have been concluded for years through 2002 . aon has concluded income tax examinations in its primary international jurisdictions through 2004. .
entergy gulf states , inc . management's financial discussion and analysis .
what were are the deferred fuel costs as a percentage of the total fuel write-offs in 2002?
the volume/weather variance was due to higher electric sales volume in the service territory . billed usage increased a total of 517 gwh in the residential and commercial sectors . the increase was partially offset by a decrease in industrial usage of 470 gwh due to the loss of two large industrial customers to cogeneration . the customers accounted for approximately 1% ( 1 % ) of entergy gulf states' net revenue in 2002 . in 2002 , deferred fuel costs of $ 8.9 million related to a texas fuel reconciliation case were written off and $ 6.5 million in expense resulted from an adjustment in the deregulated asset plan percentage as the result of a power uprate at river bend . the increase in net wholesale revenue was primarily due to an increase in sales volume to municipal and co- op customers and also to affiliated systems related to entergy's generation resource planning . the base rate decreases were effective june 2002 and january 2003 , both in the louisiana jurisdiction . the january 2003 base rate decrease of $ 22.1 million had a minimal impact on net income due to a corresponding reduction in nuclear depreciation and decommissioning expenses associated with the change in accounting to reflect an assumed extension of river bend's useful life . in 2002 , a gain of $ 15.2 million was recognized for the louisiana portion of the 1988 nelson units 1 and 2 sale . entergy gulf states received approval from the lpsc to discontinue applying amortization of the gain against recoverable fuel , resulting in the recognition of the deferred gain in income . rate refund provisions caused a decrease in net revenue due to additional provisions recorded in 2003 compared to 2002 for potential rate actions and refunds . gross operating revenues and fuel and purchased power expenses gross operating revenues increased primarily due to an increase of $ 440.2 million in fuel cost recovery revenues as a result of higher fuel rates in both the louisiana and texas jurisdictions . fuel and purchased power expenses increased $ 471.1 million due to an increase in the market prices of natural gas and purchased power . other income statement variances 2004 compared to 2003 other operation and maintenance expenses decreased primarily due to : 2022 voluntary severance program accruals of $ 22.5 million in 2003 ; and 2022 a decrease of $ 4.3 million in nuclear material and labor costs due to reduced staff in 2004. .
notes to consolidated financial statements at december 31 , 2007 , future minimum rental payments required under operating leases for continuing operations that have initial or remaining noncancelable lease terms in excess of one year , net of sublease rental income , most of which pertain to real estate leases , are as follows : ( millions ) .
assuming that actual net rent expense will be the same as presented in the table , what would be the growth rate in the net rent expense from 2008 to 2009?
aon corporation .
entergy new orleans , inc . management 2019s financial discussion and analysis the volume/weather variance is primarily due to an increase in electricity usage in the residential and commercial sectors due in part to a 4% ( 4 % ) increase in the average number of residential customers and a 3% ( 3 % ) increase in the average number of commercial customers , partially offset by the effect of less favorable weather on residential sales . gross operating revenues gross operating revenues decreased primarily due to : a decrease of $ 16.2 million in electric fuel cost recovery revenues due to lower fuel rates ; a decrease of $ 15.4 million in gross gas revenues primarily due to lower fuel cost recovery revenues as a result of lower fuel rates and the effect of milder weather ; and formula rate plan decreases effective october 2010 and october 2011 , as discussed above . the decrease was partially offset by an increase in gross wholesale revenue due to increased sales to affiliated customers and more favorable volume/weather , as discussed above . 2010 compared to 2009 net revenue consists of operating revenues net of : 1 ) fuel , fuel-related expenses , and gas purchased for resale , 2 ) purchased power expenses , and 3 ) other regulatory charges ( credits ) . following is an analysis of the change in net revenue comparing 2010 to 2009 . amount ( in millions ) .
what is the growth rate in net revenue from 2009 to 2010?
the volume/weather variance is primarily due to an increase of 348 gwh , or 7% ( 7 % ) , in billed retail electricity usage primarily due to more favorable weather compared to last year . the net gas revenue variance is primarily due to more favorable weather compared to last year , along with the recognition of a gas regulatory asset associated with the settlement of entergy new orleans 2019s electric and gas formula rate plans . see note 2 to the financial statements for further discussion of the formula rate plan settlement . the effect of 2009 rate case settlement variance results from the april 2009 settlement of entergy new orleans 2019s rate case , and includes the effects of realigning non-fuel costs associated with the operation of grand gulf from the fuel adjustment clause to electric base rates effective june 2009 . see note 2 to the financial statements for further discussion of the rate case settlement . other income statement variances 2011 compared to 2010 other operation and maintenance expenses decreased primarily due to the deferral in 2011 of $ 13.4 million of 2010 michoud plant maintenance costs pursuant to the settlement of entergy new orleans 2019s 2010 test year formula rate plan filing approved by the city council in september 2011 and a decrease of $ 8.0 million in fossil- fueled generation expenses due to higher plant outage costs in 2010 due to a greater scope of work at the michoud plant . see note 2 to the financial statements for more discussion of the 2010 test year formula rate plan filing. .
entergy louisiana , inc . management's financial discussion and analysis setting any of entergy louisiana's rates . therefore , to the extent entergy louisiana's use of the proceeds would ordinarily have reduced its rate base , no change in rate base shall be reflected for ratemaking purposes . the sec approval for additional return of equity capital is now expired . entergy louisiana's receivables from or ( payables to ) the money pool were as follows as of december 31 for each of the following years: .
what is the the net issuance of long-term debt as a percentage of the decrease in net cash used by financing activities in 2004?
money pool activity used $ 81.9 million of entergy louisiana's operating cash flow in 2004 , provided $ 60.2 million in 2003 , and used $ 15.0 million in 2002 . see note 4 to the domestic utility companies and system energy financial statements for a description of the money pool . investing activities the decrease of $ 25.1 million in net cash used by investing activities in 2004 was primarily due to decreased spending on customer service projects , partially offset by increases in spending on transmission projects and fossil plant projects . the increase of $ 56.0 million in net cash used by investing activities in 2003 was primarily due to increased spending on customer service , transmission , and nuclear projects . financing activities the decrease of $ 404.4 million in net cash used by financing activities in 2004 was primarily due to : 2022 the net issuance of $ 98.0 million of long-term debt in 2004 compared to the retirement of $ 261.0 million in 2022 a principal payment of $ 14.8 million in 2004 for the waterford lease obligation compared to a principal payment of $ 35.4 million in 2003 ; and 2022 a decrease of $ 29.0 million in common stock dividends paid . the decrease of $ 105.5 million in net cash used by financing activities in 2003 was primarily due to : 2022 a decrease of $ 125.9 million in common stock dividends paid ; and 2022 the repurchase of $ 120 million of common stock from entergy corporation in 2002 . the decrease in net cash used in 2003 was partially offset by the following : 2022 the retirement in 2003 of $ 150 million of 8.5% ( 8.5 % ) series first mortgage bonds compared to the net retirement of $ 134.6 million of first mortgage bonds in 2002 ; and 2022 principal payments of $ 35.4 million in 2003 for the waterford 3 lease obligation compared to principal payments of $ 15.9 million in 2002 . see note 5 to the domestic utility companies and system energy financial statements for details of long-term debt . uses of capital entergy louisiana requires capital resources for : 2022 construction and other capital investments ; 2022 debt and preferred stock maturities ; 2022 working capital purposes , including the financing of fuel and purchased power costs ; and 2022 dividend and interest payments. .