alanslzr/finqa-rag huggingface dataset:
Financial report context:
the company granted 1020 performance shares . the vesting of these shares is contingent on meeting stated goals over a performance period . beginning with restricted stock grants in september 2010 , dividends are accrued on restricted class a common stock and restricted stock units and are paid once the restricted stock vests . the following table summarizes restricted stock and performance shares activity for 2010 : number of shares weighted average grant date fair value .

Financial table:
number of shares: outstanding at december 31 2009; weighted average grant date fair value: 116677; column_3: $ 280
number of shares: granted; weighted average grant date fair value: 134245; column_3: 275
number of shares: vested; weighted average grant date fair value: -34630 ( 34630 ); column_3: 257
number of shares: cancelled; weighted average grant date fair value: -19830 ( 19830 ); column_3: 260
number of shares: outstanding at december 31 2010; weighted average grant date fair value: 196462; column_3: 283

Additional report context:
the total fair value of restricted stock that vested during the years ended december 31 , 2010 , 2009 and 2008 , was $ 10.3 million , $ 6.2 million and $ 2.5 million , respectively . eligible employees may acquire shares of cme group 2019s class a common stock using after-tax payroll deductions made during consecutive offering periods of approximately six months in duration . shares are purchased at the end of each offering period at a price of 90% ( 90 % ) of the closing price of the class a common stock as reported on the nasdaq . compensation expense is recognized on the dates of purchase for the discount from the closing price . in 2010 , 2009 and 2008 , a total of 4371 , 4402 and 5600 shares , respectively , of class a common stock were issued to participating employees . these shares are subject to a six-month holding period . annual expense of $ 0.1 million for the purchase discount was recognized in 2010 , 2009 and 2008 , respectively . non-executive directors receive an annual award of class a common stock with a value equal to $ 75000 . non-executive directors may also elect to receive some or all of the cash portion of their annual stipend , up to $ 25000 , in shares of stock based on the closing price at the date of distribution . as a result , 7470 , 11674 and 5509 shares of class a common stock were issued to non-executive directors during 2010 , 2009 and 2008 , respectively . these shares are not subject to any vesting restrictions . expense of $ 2.4 million , $ 2.5 million and $ 2.4 million related to these stock-based payments was recognized for the years ended december 31 , 2010 , 2009 and 2008 , respectively. .

Question: for 2010 , assuming all of the outstanding restricted stock and performance shares were exercised , what would be the increase in stockholders equity?
Answer: 55598746
Financial report context:
supplementary information on oil and gas producing activities ( unaudited ) c o n t i n u e d summary of changes in standardized measure of discounted future net cash flows relating to proved oil and gas reserves ( in millions ) 2006 2005 2004 sales and transfers of oil and gas produced , net of production , transportation and administrative costs $ ( 5312 ) $ ( 3754 ) $ ( 2689 ) net changes in prices and production , transportation and administrative costs related to future production ( 1342 ) 6648 771 .

Financial table:
( in millions ): sales and transfers of oil and gas produced net of production transportation and administrative costs; 2006: $ -5312 ( 5312 ); 2005: $ -3754 ( 3754 ); 2004: $ -2689 ( 2689 )
( in millions ): net changes in prices and production transportation and administrative costs related to future production; 2006: -1342 ( 1342 ); 2005: 6648; 2004: 771
( in millions ): extensions discoveries and improved recovery less related costs; 2006: 1290; 2005: 700; 2004: 1349
( in millions ): development costs incurred during the period; 2006: 1251; 2005: 1030; 2004: 609
( in millions ): changes in estimated future development costs; 2006: -527 ( 527 ); 2005: -552 ( 552 ); 2004: -628 ( 628 )
( in millions ): revisions of previous quantity estimates; 2006: 1319; 2005: 820; 2004: 948
( in millions ): net changes in purchases and sales of minerals in place; 2006: 30; 2005: 4557; 2004: 33
( in millions ): accretion of discount; 2006: 1882; 2005: 1124; 2004: 757
( in millions ): net change in income taxes; 2006: -660 ( 660 ); 2005: -6694 ( 6694 ); 2004: -627 ( 627 )
( in millions ): timing and other; 2006: -14 ( 14 ); 2005: 307; 2004: 97
( in millions ): net change for the year; 2006: -2083 ( 2083 ); 2005: 4186; 2004: 620
( in millions ): beginning of year; 2006: 10601; 2005: 6415; 2004: 5795
( in millions ): end of year; 2006: $ 8518; 2005: $ 10601; 2004: $ 6415
( in millions ): net change for the year from discontinued operations; 2006: $ -216 ( 216 ); 2005: $ 162; 2004: $ -152 ( 152 )

Additional report context:
.

Question: if the 2007 year shows the same rate of change as 2006 , what would the projected ending cash flow balance be , in millions?
Answer: 6844
Financial report context:
entergy new orleans , inc . management's financial discussion and analysis results of operations net income ( loss ) 2004 compared to 2003 net income increased $ 20.2 million primarily due to higher net revenue . 2003 compared to 2002 entergy new orleans had net income of $ 7.9 million in 2003 compared to a net loss in 2002 . the increase was due to higher net revenue and lower interest expense , partially offset by higher other operation and maintenance expenses and depreciation and amortization expenses . net revenue 2004 compared to 2003 net revenue , which is entergy new orleans' 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. .

Financial table:
( in millions ): 2003 net revenue; column_2: $ 208.3
( in millions ): base rates; column_2: 10.6
( in millions ): volume/weather; column_2: 8.3
( in millions ): 2004 deferrals; column_2: 7.5
( in millions ): price applied to unbilled electric sales; column_2: 3.7
( in millions ): other; column_2: 0.6
( in millions ): 2004 net revenue; column_2: $ 239.0

Additional report context:
the increase in base rates was effective june 2003 . the rate increase is discussed in note 2 to the domestic utility companies and system energy financial statements . the volume/weather variance is primarily due to increased billed electric usage of 162 gwh in the industrial service sector . the increase was partially offset by milder weather in the residential and commercial sectors . the 2004 deferrals variance is due to the deferral of voluntary severance plan and fossil plant maintenance expenses in accordance with a stipulation approved by the city council in august 2004 . the stipulation allows for the recovery of these costs through amortization of a regulatory asset . the voluntary severance plan and fossil plant maintenance expenses are being amortized over a five-year period that became effective january 2004 and january 2003 , respectively . the formula rate plan is discussed in note 2 to the domestic utility companies and system energy financial statements . the price applied to unbilled electric sales variance is due to an increase in the fuel price applied to unbilled sales. .

Question: what is the percent change in net revenue from 2003 to 2004?
Answer: 14.7%
Financial report context:
sources and uses of cash ( in millions ) in summary , our cash flows for each period were as follows : years ended ( in millions ) dec 29 , dec 30 , dec 31 .

Financial table:
years ended ( in millions ): net cash provided by operating activities; dec 292018: $ 29432; dec 302017: $ 22110; dec 312016: $ 21808
years ended ( in millions ): net cash used for investing activities; dec 292018: -11239 ( 11239 ); dec 302017: -15762 ( 15762 ); dec 312016: -25817 ( 25817 )
years ended ( in millions ): net cash provided by ( used for ) financing activities; dec 292018: -18607 ( 18607 ); dec 302017: -8475 ( 8475 ); dec 312016: -5739 ( 5739 )
years ended ( in millions ): net increase ( decrease ) in cash and cash equivalents; dec 292018: $ -414 ( 414 ); dec 302017: $ -2127 ( 2127 ); dec 312016: $ -9748 ( 9748 )

Additional report context:
md&a consolidated results and analysis 40 .

Question: what was the percentage change in net cash provided by operating activities between 2017 and 2018?
Answer: 33%
Financial report context:
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: .

Financial table:
2004: ( in thousands ); 2003: ( in thousands ); 2002: ( in thousands ); 2001: ( in thousands )
2004: $ 40549; 2003: ( $ 41317 ); 2002: $ 18854; 2001: $ 3812

Additional report context:
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. .

Question: what is the difference of the payment for waterford lease obligation between 2003 and 2004?
Answer: 20.6
Financial report context:
3 . dividends from subsidiaries and affiliates cash dividends received from consolidated subsidiaries and from affiliates accounted for by the equity method were as follows ( in millions ) : .

Financial table:
2003: subsidiaries; 2002: $ 807; 2001: $ 771; column_4: $ 1038
2003: affiliates; 2002: 43; 2001: 44; column_4: 21

Additional report context:
4 . guarantees and letters of credit guarantees 2014in connection with certain of its project financing , acquisition , and power purchase agreements , the company has expressly undertaken limited obligations and commitments , most of which will only be effective or will be terminated upon the occurrence of future events . these obligations and commitments , excluding those collateralized by letter of credit and other obligations discussed below , were limited as of december 31 , 2003 , by the terms of the agreements , to an aggregate of approximately $ 515 million representing 55 agreements with individual exposures ranging from less than $ 1 million up to $ 100 million . of this amount , $ 147 million represents credit enhancements for non-recourse debt , and $ 38 million commitments to fund its equity in projects currently under development or in construction . letters of credit 2014at december 31 , 2003 , the company had $ 89 million in letters of credit outstanding representing 9 agreements with individual exposures ranging from less than $ 1 million up to $ 36 million , which operate to guarantee performance relating to certain project development and construction activities and subsidiary operations . the company pays a letter of credit fee ranging from 0.5% ( 0.5 % ) to 5.00% ( 5.00 % ) per annum on the outstanding amounts . in addition , the company had $ 4 million in surety bonds outstanding at december 31 , 2003. .

Question: at december 31 , 2003 , what was the range of exposures for the outstanding letters of credit?
Answer: 35000000
Financial report context:
underlying physical transaction occurs . we have not qualified commodity derivative instruments used in our osm or rm&t segments for hedge accounting . as a result , we recognize in net income all changes in the fair value of derivative instruments used in those operations . open commodity derivative positions as of december 31 , 2008 and sensitivity analysis at december 31 , 2008 , our e&p segment held open derivative contracts to mitigate the price risk on natural gas held in storage or purchased to be marketed with our own natural gas production in amounts that were in line with normal levels of activity . at december 31 , 2008 , we had no significant open derivative contracts related to our future sales of liquid hydrocarbons and natural gas and therefore remained substantially exposed to market prices of these commodities . the osm segment holds crude oil options which were purchased by western for a three year period ( january 2007 to december 2009 ) . the premiums for the purchased put options had been partially offset through the sale of call options for the same three-year period , resulting in a net premium liability . payment of the net premium liability is deferred until the settlement of the option contracts . as of december 31 , 2008 , the following put and call options were outstanding: .

Financial table:
option expiration date: option contract volumes ( barrels per day ) :
option expiration date: put options purchased; 2009: 20000
option expiration date: call options sold; 2009: 15000
option expiration date: average exercise price ( dollars per barrel ) :
option expiration date: put options; 2009: $ 50.50
option expiration date: call options; 2009: $ 90.50

Additional report context:
in the first quarter of 2009 , we sold derivative instruments at an average exercise price of $ 50.50 which effectively offset the open put options for the remainder of 2009 . at december 31 , 2008 , the number of open derivative contracts held by our rm&t segment was lower than in previous periods . starting in the second quarter of 2008 , we decreased our use of derivatives to mitigate crude oil price risk between the time that domestic spot crude oil purchases are priced and when they are actually refined into salable petroleum products . instead , we are addressing this price risk through other means , including changes in contractual terms and crude oil acquisition practices . additionally , in previous periods , certain contracts in our rm&t segment for the purchase or sale of commodities were not qualified or designated as normal purchase or normal sales under generally accepted accounting principles and therefore were accounted for as derivative instruments . during the second quarter of 2008 , as we decreased our use of derivatives , we began to designate such contracts for the normal purchase and normal sale exclusion. .

Question: using the above listed average exercise price , what were the value of the call options sold?
Answer: 1357500.00
Financial report context:
there were no changes in the company 2019s valuation techniques used to measure fair values on a recurring basis as a result of adopting asc 820 . pca had no assets or liabilities that were measured on a nonrecurring basis . 11 . stockholders 2019 equity on october 17 , 2007 , pca announced that its board of directors authorized a $ 150.0 million common stock repurchase program . there is no expiration date for the common stock repurchase program . through december 31 , 2008 , the company repurchased 3818729 shares of common stock , with 3142600 shares repurchased during 2008 and 676129 shares repurchased during 2007 . all repurchased shares were retired prior to december 31 , 2008 . there were no shares repurchased in 2009 . as of december 31 , 2009 , $ 65.0 million of the $ 150.0 million authorization remained available for repurchase of the company 2019s common stock . 12 . commitments and contingencies capital commitments the company had authorized capital commitments of approximately $ 41.7 million and $ 43.0 million as of december 31 , 2009 and 2008 , respectively , in connection with the expansion and replacement of existing facilities and equipment . in addition , commitments at december 31 , 2009 for the major energy optimization projects at its counce and valdosta mills totaled $ 156.3 million . lease obligations pca leases space for certain of its facilities and cutting rights to approximately 91000 acres of timberland under long-term leases . the company also leases equipment , primarily vehicles and rolling stock , and other assets under long-term leases with a duration of two to seven years . the minimum lease payments under non-cancelable operating leases with lease terms in excess of one year are as follows: .

Financial table:
( in thousands ): 2010; column_2: $ 28162
( in thousands ): 2011; column_2: 25181
( in thousands ): 2012; column_2: 17338
( in thousands ): 2013; column_2: 11557
( in thousands ): 2014; column_2: 7742
( in thousands ): thereafter; column_2: 18072
( in thousands ): total; column_2: $ 108052

Additional report context:
total lease expense , including base rent on all leases and executory costs , such as insurance , taxes , and maintenance , for the years ended december 31 , 2009 , 2008 and 2007 was $ 41.3 million , $ 41.6 million and $ 39.8 million , respectively . these costs are included in cost of goods sold and selling and administrative expenses . pca was obligated under capital leases covering buildings and machinery and equipment in the amount of $ 23.1 million and $ 23.7 million at december 31 , 2009 and 2008 , respectively . during the fourth quarter of 2008 , the company entered into a capital lease relating to buildings and machinery , totaling $ 23.9 million , payable over 20 years . this capital lease amount is a non-cash transaction and , accordingly , has been excluded packaging corporation of america notes to consolidated financial statements ( continued ) december 31 , 2009 .

Question: what percentage of total minimum lease payments under non-cancelable operating leases with lease terms in excess of one year are due in 2011?
Answer: 23%
Financial report context:
free cash flow conversion rate and total cash returned to shareholders as a percentage of free cash we believe these measures provide useful information to investors because they are important for assessing our efficiency in converting earnings to cash and returning cash to shareholders . the calculation of free cash flow conversion rate and net cash provided by operating activities conversion rate , its equivalent gaap measure , follows: .

Financial table:
in millions: net earnings including earnings attributable to redeemable and noncontrolling interests asreported; fiscal 2018: $ 2163.0
in millions: provisional net tax benefit ( a ); fiscal 2018: $ -523.5 ( 523.5 )
in millions: mark-to-marketeffects net of tax ( b ); fiscal 2018: -22.1 ( 22.1 )
in millions: acquisition transaction and integration costs net of tax ( c ); fiscal 2018: 58.5
in millions: restructuring costs net of tax ( d ); fiscal 2018: 61.4
in millions: project-related costs net of tax ( d ); fiscal 2018: 8.0
in millions: intangible asset impairments net of tax ( e ); fiscal 2018: 64.9
in millions: tax adjustment ( a ); fiscal 2018: 40.9
in millions: cpw restructuring costs net of tax; fiscal 2018: 1.8
in millions: adjusted net earnings including earnings attributable to redeemable and noncontrollinginterests; fiscal 2018: 1852.9
in millions: net cash provided by operating activities; fiscal 2018: 2841.0
in millions: purchases of land buildings and equipment; fiscal 2018: -622.7 ( 622.7 )
in millions: free cash flow; fiscal 2018: $ 2218.3
in millions: net cash provided by operating activities conversion rate; fiscal 2018: 131% ( 131 % )
in millions: free cash flow conversion rate; fiscal 2018: 120% ( 120 % )

Additional report context:
( a ) see note 14 to the consolidated financial statements in item 8 of this report . ( b ) see note 7 to the consolidated financial statements in item 8 of this report . ( c ) see note 3 to the consolidated financial statements in item 8 of this report . ( d ) see note 4 to the consolidated financial statements in item 8 of this report . ( e ) see note 6 to the consolidated financial statements in item 8 of this report . see our reconciliation below of the effective income tax rate as reported to the effective income tax rate excluding certain items affecting comparability for the tax impact of each item affecting comparability. .

Question: in 2018 what was the ratio of the net earnings to the net cash provided by operating activities
Answer: 0.761