bevaya/FinQA huggingface dataset:
tower cash flow , adjusted consolidated cash flow and non-tower cash flow are considered non-gaap financial measures . we are required to provide these financial metrics by the indentures for our 7.50% ( 7.50 % ) notes and 7.125% ( 7.125 % ) notes , and we have included them below because we consider the indentures for these notes to be material agreements , the covenants related to tower cash flow , adjusted consolidated cash flow and non-tower cash flow to be material terms of the indentures , and information about compliance with such covenants to be material to an investor 2019s understanding of our financial results and the impact of those results on our liquidity . the following table presents tower cash flow , adjusted consolidated cash flow and non-tower cash flow for the company and its restricted subsidiaries , as defined in the indentures for the applicable notes ( in thousands ) : .

Table: tower cash flow for the three months ended december 31 2008 $ 188449 consolidated cash flow for the twelve months ended december 31 2008 726954 less : tower cash flow for the twelve months ended december 31 2008 -741565 ( 741565 ) plus : four times tower cash flow for the three months ended december 31 2008 753798 adjusted consolidated cash flow for the twelve months ended december 31 2008 739187 non-tower cash flow for the twelve months ended december 31 2008 $ -14611 ( 14611 )

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Question: what portion of the adjusted consolidated cash flow for the twelve months ended december 31 , 2008 is related to tower cash flow?
Answer: 102.0%
Calculation: divide(753798, 739187)
intel corporation notes to consolidated financial statements ( continued ) the aggregate fair value of awards that vested in 2015 was $ 1.5 billion ( $ 1.1 billion in 2014 and $ 1.0 billion in 2013 ) , which represents the market value of our common stock on the date that the rsus vested . the grant-date fair value of awards that vested in 2015 was $ 1.1 billion ( $ 949 million in 2014 and $ 899 million in 2013 ) . the number of rsus vested includes shares of common stock that we withheld on behalf of employees to satisfy the minimum statutory tax withholding requirements . rsus that are expected to vest are net of estimated future forfeitures . as of december 26 , 2015 , there was $ 1.8 billion in unrecognized compensation costs related to rsus granted under our equity incentive plans . we expect to recognize those costs over a weighted average period of 1.2 years . stock option awards as of december 26 , 2015 , options outstanding that have vested and are expected to vest were as follows : number of options ( in millions ) weighted average exercise weighted average remaining contractual ( in years ) aggregate intrinsic ( in millions ) .

Table: number ofoptions ( in millions ) weightedaverageexerciseprice weightedaverageremainingcontractualterm ( in years ) aggregateintrinsicvalue ( in millions ) vested 43.8 $ 21.07 1.8 $ 609 expected to vest 9.6 $ 24.07 4.1 $ 104 total 53.4 $ 21.61 2.2 $ 713

aggregate intrinsic value represents the difference between the exercise price and $ 34.98 , the closing price of our common stock on december 24 , 2015 , as reported on the nasdaq global select market , for all in-the-money options outstanding . options outstanding that are expected to vest are net of estimated future option forfeitures . options with a fair value of $ 42 million completed vesting in 2015 ( $ 68 million in 2014 and $ 186 million in 2013 ) . as of december 26 , 2015 , there was $ 13 million in unrecognized compensation costs related to stock options granted under our equity incentive plans . we expect to recognize those costs over a weighted average period of approximately eight months. .

Question: what percentage of stock option awards are expected to vest as of december 26 , 2015?
Answer: 18%
Calculation: divide(9.6, 53.4)
the graph below shows a five-year comparison of the cumulative shareholder return on our common stock with the cumulative total return of the standard & poor 2019s ( s&p ) mid cap 400 index and the russell 1000 index , both of which are published indices . comparison of five-year cumulative total return from december 31 , 2011 to december 31 , 2016 assumes $ 100 invested with reinvestment of dividends period indexed returns .

Table: company/index baseperiod 12/31/11 baseperiod 12/31/12 baseperiod 12/31/13 baseperiod 12/31/14 baseperiod 12/31/15 12/31/16 a . o . smith corporation 100.0 159.5 275.8 292.0 401.0 501.4 s&p mid cap 400 index 100.0 117.9 157.4 172.8 169.0 204.1 russell 1000 index 100.0 116.4 155.0 175.4 177.0 198.4

2011 2012 2013 2014 2015 2016 smith ( a o ) corp s&p midcap 400 index russell 1000 index .

Question: what was the difference in total return for the five year period ended 12/31/16 between a . o . smith corporation and the russell 1000 index?
Answer: 303%
Calculation: divide(subtract(198.4, const_100), const_100)
s c h e d u l e i v ace limited and subsidiaries s u p p l e m e n t a l i n f o r m a t i o n c o n c e r n i n g r e i n s u r a n c e premiums earned for the years ended december 31 , 2009 , 2008 , and 2007 ( in millions of u.s . dollars , except for percentages ) direct amount ceded to companies assumed from other companies net amount percentage of amount assumed to .

Table: for the years ended december 31 2009 2008 and 2007 ( in millions of u.s . dollars except for percentages ) direct amount ceded to other companies assumed from other companies net amount percentage of amount assumed to net 2009 $ 15415 $ 5943 $ 3768 $ 13240 28% ( 28 % ) 2008 $ 16087 $ 6144 $ 3260 $ 13203 25% ( 25 % ) 2007 $ 14673 $ 5834 $ 3458 $ 12297 28% ( 28 % )

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Question: what percent of the direct amount is ceded to other companies in 2009 , ( in millions ) ?
Answer: 38.6%
Calculation: divide(5943, 15415)
entergy corporation and subsidiaries management's financial discussion and analysis net revenue 2004 compared to 2003 net revenue , which is entergy's measure of gross margin , consists of operating revenues net of : 1 ) fuel , fuel-related , and purchased power expenses and 2 ) other regulatory credits . following is an analysis of the change in net revenue comparing 2004 to 2003. .

Table: ( in millions ) 2003 net revenue $ 4214.5 volume/weather 68.3 summer capacity charges 17.4 base rates 10.6 deferred fuel cost revisions -46.3 ( 46.3 ) price applied to unbilled sales -19.3 ( 19.3 ) other -1.2 ( 1.2 ) 2004 net revenue $ 4244.0

the volume/weather variance resulted primarily from increased usage , partially offset by the effect of milder weather on sales during 2004 compared to 2003 . billed usage increased a total of 2261 gwh in the industrial and commercial sectors . the summer capacity charges variance was due to the amortization in 2003 at entergy gulf states and entergy louisiana of deferred capacity charges for the summer of 2001 . entergy gulf states' amortization began in june 2002 and ended in may 2003 . entergy louisiana's amortization began in august 2002 and ended in july 2003 . base rates increased net revenue due to a base rate increase at entergy new orleans that became effective in june 2003 . the deferred fuel cost revisions variance resulted primarily from a revision in 2003 to an unbilled sales pricing estimate to more closely align the fuel component of that pricing with expected recoverable fuel costs at entergy louisiana . deferred fuel cost revisions also decreased net revenue due to a revision in 2004 to the estimate of fuel costs filed for recovery at entergy arkansas in the march 2004 energy cost recovery rider . the price applied to unbilled sales variance resulted from a decrease in fuel price in 2004 caused primarily by the effect of nuclear plant outages in 2003 on average fuel costs . gross operating revenues and regulatory credits gross operating revenues include an increase in fuel cost recovery revenues of $ 475 million and $ 18 million in electric and gas sales , respectively , primarily due to higher fuel rates in 2004 resulting from increases in the market prices of purchased power and natural gas . as such , this revenue increase is offset by increased fuel and purchased power expenses . other regulatory credits increased primarily due to the following : 2022 cessation of the grand gulf accelerated recovery tariff that was suspended in july 2003 ; 2022 the amortization in 2003 of deferred capacity charges for summer 2001 power purchases at entergy gulf states and entergy louisiana ; 2022 the deferral in 2004 of $ 14.3 million of capacity charges related to generation resource planning as allowed by the lpsc ; 2022 the deferral in 2004 by entergy louisiana of $ 11.4 million related to the voluntary severance program , in accordance with a proposed stipulation entered into with the lpsc staff ; and .

Question: what is the net change in net revenue during 2004 for entergy corporation?
Answer: 29.5
Calculation: subtract(4244.0, 4214.5)
schedule iii page 6 of 6 host hotels & resorts , inc. , and subsidiaries host hotels & resorts , l.p. , and subsidiaries real estate and accumulated depreciation december 31 , 2018 ( in millions ) ( b ) the change in accumulated depreciation and amortization of real estate assets for the fiscal years ended december 31 , 2018 , 2017 and 2016 is as follows: .

Table: balance at december 31 2015 $ 5666 depreciation and amortization 572 dispositions and other -159 ( 159 ) depreciation on assets held for sale -130 ( 130 ) balance at december 31 2016 5949 depreciation and amortization 563 dispositions and other -247 ( 247 ) depreciation on assets held for sale 7 balance at december 31 2017 6272 depreciation and amortization 546 dispositions and other -344 ( 344 ) depreciation on assets held for sale -101 ( 101 ) balance at december 31 2018 $ 6373

( c ) the aggregate cost of real estate for federal income tax purposes is approximately $ 10458 million at december 31 , 2018 . ( d ) the total cost of properties excludes construction-in-progress properties. .

Question: what was the net change in millions in the accumulated depreciation and amortization of real estate assets from 2016 to 2017?
Answer: 323
Calculation: subtract(6272, 5949)
22 2002subsequent events in january 2011 , we purchased cif 2019s 49.9% ( 49.9 % ) interest in 521 fifth avenue , thereby assuming full ownership of the building . the transaction values the consolidated interest at approximately $ 245.7 a0million . in january 2011 , we repaid our $ 84.8 a0million , 5.15% ( 5.15 % ) unsecured notes at par on their maturity date . in january 2011 , we , along with the moinian group , completed the recapitalization of 3 columbus circle . the recapitalization included a $ 138 a0million equity investment by sl a0green , a portion of which was in the form of sl a0green operating partnership units . we believe the property is now fully capitalized for all costs necessary to complete the redevelop- ment and lease-up of the building . the previously existing mortgage has been refinanced with a bridge loan provided by sl a0green and deutsche bank , which we intend to be further refinanced by third-party lenders at a later date . on february a010 , 2011 , the company and the operating partnership entered into atm equity offering sales agreements with each of merrill lynch , pierce , fenner a0& smith incorporated and morgan stanley a0& a0co . incorporated , to sell shares of the company 2019s common stock , from time to time , through a $ 250.0 a0 million 201cat the market 201d equity offering program under which merrill lynch , pierce , fenner a0& smith incorporated and morgan stanley a0& a0co . incorporated are acting as sales agents . as of february a022 , 2011 , we sold approximately 2.0 a0million shares our common stock through the program for aggregate proceeds of $ 144.1 a0million . 2009 quarter ended december a031 september a030 june a030 march a031 .

Table: 2009 quarter ended december 31 september 30 june 30 march 31 total revenues $ 243040 $ 245769 $ 248251 $ 258787 income ( loss ) net of noncontrolling interests and before gains on sale -380 ( 380 ) 4099 -10242 ( 10242 ) -26600 ( 26600 ) equity in net gain ( loss ) on sale of interest in unconsolidated joint venture/ real estate 2014 -157 ( 157 ) -2693 ( 2693 ) 9541 gain on early extinguishment of debt 606 8368 29321 47712 gain ( loss ) on equity investment in marketable securities -232 ( 232 ) -52 ( 52 ) 127 -807 ( 807 ) net income from discontinued operations 1593 1863 999 1319 gain ( loss ) on sale of discontinued operations -1741 ( 1741 ) -11672 ( 11672 ) 2014 6572 net income ( loss ) attributable to sl green -154 ( 154 ) 2449 17512 37737 preferred stock dividends -4969 ( 4969 ) -4969 ( 4969 ) -4969 ( 4969 ) -4969 ( 4969 ) net income ( loss ) attributable to sl green common stockholders $ -5123 ( 5123 ) $ -2520 ( 2520 ) $ 12543 $ 32768 net income ( loss ) per common share-basic $ -0.07 ( 0.07 ) $ -0.03 ( 0.03 ) $ 0.19 $ 0.57 net income ( loss ) per common share-diluted $ -0.07 ( 0.07 ) $ -0.03 ( 0.03 ) $ 0.18 $ 0.57

88 sl green realty corp . 2010 annual report notes to consolidated financial statements .

Question: in 2009 what was the average revenues per quarter in millions
Answer: 248961.75
Calculation: divide(add(258787, add(248251, add(243040, 245769))), const_4)
entergy corporation and subsidiaries management 2019s financial discussion and analysis net revenue utility following is an analysis of the change in net revenue comparing 2014 to 2013 . amount ( in millions ) .

Table: amount ( in millions ) 2013 net revenue $ 5524 retail electric price 135 asset retirement obligation 56 volume/weather 36 miso deferral 16 net wholesale revenue -29 ( 29 ) other -3 ( 3 ) 2014 net revenue $ 5735

the retail electric price variance is primarily due to : 2022 increases in the energy efficiency rider at entergy arkansas , as approved by the apsc , effective july 2013 and july 2014 . energy efficiency revenues are offset by costs included in other operation and maintenance expenses and have minimal effect on net income ; 2022 the effect of the apsc 2019s order in entergy arkansas 2019s 2013 rate case , including an annual base rate increase effective january 2014 offset by a miso rider to provide customers credits in rates for transmission revenue received through miso ; 2022 a formula rate plan increase at entergy mississippi , as approved by the mspc , effective september 2013 ; 2022 an increase in entergy mississippi 2019s storm damage rider , as approved by the mpsc , effective october 2013 . the increase in the storm damage rider is offset by other operation and maintenance expenses and has no effect on net income ; 2022 an annual base rate increase at entergy texas , effective april 2014 , as a result of the puct 2019s order in the september 2013 rate case ; and 2022 a formula rate plan increase at entergy louisiana , as approved by the lpsc , effective december 2014 . see note 2 to the financial statements for a discussion of rate proceedings . the asset retirement obligation affects net revenue because entergy records a regulatory debit or credit for the difference between asset retirement obligation-related expenses and trust earnings plus asset retirement obligation- related costs collected in revenue . the variance is primarily caused by increases in regulatory credits because of decreases in decommissioning trust earnings and increases in depreciation and accretion expenses and increases in regulatory credits to realign the asset retirement obligation regulatory assets with regulatory treatment . the volume/weather variance is primarily due to an increase of 3129 gwh , or 3% ( 3 % ) , in billed electricity usage primarily due to an increase in sales to industrial customers and the effect of more favorable weather on residential sales . the increase in industrial sales was primarily due to expansions , recovery of a major refining customer from an unplanned outage in 2013 , and continued moderate growth in the manufacturing sector . the miso deferral variance is primarily due to the deferral in 2014 of the non-fuel miso-related charges , as approved by the lpsc and the mpsc , partially offset by the deferral in april 2013 , as approved by the apsc , of costs incurred from march 2010 through december 2012 related to the transition and implementation of joining the miso .

Question: what is the percent change in net revenue from 2013 to 2014?
Answer: 3.82%
Calculation: divide(subtract(5735, 5524), 5524)
item 2 . properties flight equipment and fleet renewal as of december 31 , 2017 , american operated a mainline fleet of 948 aircraft . in 2017 , we continued our extensive fleet renewal program , which has provided us with the youngest fleet of the major u.s . network carriers . during 2017 , american took delivery of 57 new mainline aircraft and retired 39 mainline aircraft . we are supported by our wholly-owned and third-party regional carriers that fly under capacity purchase agreements operating as american eagle . as of december 31 , 2017 , american eagle operated 597 regional aircraft . during 2017 , we reduced our regional fleet by a net of nine aircraft , including the addition of 63 regional aircraft and retirement of 72 regional aircraft . mainline as of december 31 , 2017 , american 2019s mainline fleet consisted of the following aircraft : average seating capacity average ( years ) owned leased total .

Table: average seatingcapacity averageage ( years ) owned leased total airbus a319 128 13.8 21 104 125 airbus a320 150 16.7 10 38 48 airbus a321 178 5.4 165 54 219 airbus a330-200 251 6.0 15 2014 15 airbus a330-300 291 17.4 4 5 9 boeing 737-800 160 8.1 132 172 304 boeing 737-8 max 172 0.1 4 2014 4 boeing 757-200 180 18.1 31 3 34 boeing 767-300er 209 19.1 24 2014 24 boeing 777-200er 269 17.0 44 3 47 boeing 777-300er 310 3.8 18 2 20 boeing 787-8 226 2.1 20 2014 20 boeing 787-9 285 0.7 14 2014 14 embraer 190 99 10.2 20 2014 20 mcdonnell douglas md-80 140 21.3 13 32 45 total 10.1 535 413 948

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Question: what percent of american's total planes carried fewer than 100 pasengers?
Answer: 2.1%
Calculation: divide(20, 948)
notes to consolidated financial statements ( continued ) note 2 2014financial instruments ( continued ) typically , the company hedges portions of its forecasted foreign currency exposure associated with revenue and inventory purchases over a time horizon of up to 6 months . derivative instruments designated as cash flow hedges must be de-designated as hedges when it is probable the forecasted hedged transaction will not occur in the initially identified time period or within a subsequent 2 month time period . deferred gains and losses in other comprehensive income associated with such derivative instruments are immediately reclassified into earnings in other income and expense . any subsequent changes in fair value of such derivative instruments are also reflected in current earnings unless they are re-designated as hedges of other transactions . the company recognized net gains of approximately $ 672000 and $ 421000 in 2007 and 2006 , respectively , and a net loss of $ 1.6 million in 2005 in other income and expense related to the loss of hedge designation on discontinued cash flow hedges due to changes in the company 2019s forecast of future net sales and cost of sales and due to prevailing market conditions . as of september 29 , 2007 , the company had a net deferred gain associated with cash flow hedges of approximately $ 468000 , net of taxes , substantially all of which is expected to be reclassified to earnings by the end of the second quarter of fiscal 2008 . the net gain or loss on the effective portion of a derivative instrument designated as a net investment hedge is included in the cumulative translation adjustment account of accumulated other comprehensive income within shareholders 2019 equity . for the years ended september 29 , 2007 and september 30 , 2006 , the company had a net loss of $ 2.6 million and a net gain of $ 7.4 million , respectively , included in the cumulative translation adjustment . the company may also enter into foreign currency forward and option contracts to offset the foreign exchange gains and losses generated by the re-measurement of certain assets and liabilities recorded in non-functional currencies . changes in the fair value of these derivatives are recognized in current earnings in other income and expense as offsets to the changes in the fair value of the related assets or liabilities . due to currency market movements , changes in option time value can lead to increased volatility in other income and expense . note 3 2014consolidated financial statement details ( in millions ) other current assets .

Table: 2007 2006 vendor non-trade receivables $ 2392 $ 1593 nand flash memory prepayments 417 208 other current assets 996 469 total other current assets $ 3805 $ 2270

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Question: what was the largest amount of other current assets?
Answer: 996
Calculation: table_max(other current assets, none)
kendal vroman , 39 mr . vroman has served as our managing director , commodity products , otc services & information products since february 2010 . mr . vroman previously served as managing director and chief corporate development officer from 2008 to 2010 . mr . vroman joined us in 2001 and since then has held positions of increasing responsibility , including most recently as managing director , corporate development and managing director , information and technology services . scot e . warren , 47 mr . warren has served as our managing director , equity index products and index services since february 2010 . mr . warren previously served as our managing director , equity products since joining us in 2007 . prior to that , mr . warren worked for goldman sachs as its president , manager trading and business analysis team . prior to goldman sachs , mr . warren managed equity and option execution and clearing businesses for abn amro in chicago and was a senior consultant for arthur andersen & co . for financial services firms . financial information about geographic areas due to the nature of its business , cme group does not track revenues based upon geographic location . we do , however , track trading volume generated outside of traditional u.s . trading hours and through our international telecommunication hubs . our customers can directly access our exchanges throughout the world . the following table shows the percentage of our total trading volume on our globex electronic trading platform generated during non-u.s . hours and through our international hubs. .

Table: 2010 2009 2008 trading during non-u.s . hours 13% ( 13 % ) 9% ( 9 % ) 11% ( 11 % ) trading through telecommunication hubs 8 7 8

available information our web site is www.cmegroup.com . information made available on our web site does not constitute part of this document . we make available on our web site our annual reports on form 10-k , quarterly reports on form 10-q , current reports on form 8-k and amendments to those reports as soon as reasonably practicable after we electronically file or furnish such materials to the sec . our corporate governance materials , including our corporate governance principles , director conflict of interest policy , board of directors code of ethics , categorical independence standards , employee code of conduct and the charters for all the standing committees of our board , may also be found on our web site . copies of these materials are also available to shareholders free of charge upon written request to shareholder relations and member services , attention ms . beth hausoul , cme group inc. , 20 south wacker drive , chicago , illinois 60606. .

Question: what was the increase of trading during non u.s hours between 2009 and 2010?
Answer: 4%
Calculation: subtract(13%, 9%)
Explanation: its the variation between those percentages .