whpthomas/finqa-parquet huggingface dataset:
entergy gulf states , inc . management's financial discussion and analysis .
what is the growth rate in net revenue in 2003 for entergy gulf states , inc.?
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. .
consume significant amounts of energy , and we may in the future incur additional or increased capital , operating and other expenditures from changes due to new or increased climate-related and other environmental regulations . we could also incur substantial liabilities , including fines or sanctions , enforcement actions , natural resource damages claims , cleanup and closure costs , and third-party claims for property damage and personal injury under environmental and common laws . the foreign corrupt practices act of 1977 and local anti-bribery laws , including those in brazil , china , mexico , india and the united kingdom ( where we maintain operations directly or through a joint venture ) , prohibit companies and their intermediaries from making improper payments to government officials for the purpose of influencing official decisions . our internal control policies and procedures , or those of our vendors , may not adequately protect us from reckless or criminal acts committed or alleged to have been committed by our employees , agents or vendors . any such violations could lead to civil or criminal monetary and non-monetary penalties and/or could damage our reputation . we are subject to a number of labor and employment laws and regulations that could significantly increase our operating costs and reduce our operational flexibility . additionally , changing privacy laws in the united states ( including the california consumer privacy act , which will become effective in january 2020 ) , europe ( where the general data protection regulation became effective in 2018 ) and elsewhere have created new individual privacy rights , imposed increased obligations on companies handling personal data and increased potential exposure to fines and penalties . item 1b . unresolved staff comments there are no unresolved sec staff comments . item 2 . properties we operate locations in north america , including the majority of u.s . states , south america , europe , asia and australia . we lease our principal offices in atlanta , ga . we believe that our existing production capacity is adequate to serve existing demand for our products and consider our plants and equipment to be in good condition . our corporate and operating facilities as of september 30 , 2019 are summarized below: .
what was the ratio of the corrugated packaging number of facilities owned to those leased
the tables that follow show our annual production capacity by mill at september 30 , 2019 in thousands of tons , except for the north charleston , sc mill which reflects our capacity after the previously announced machine closure expected to occur in fiscal 2020 . our mill system production levels and operating rates may vary from year to year due to changes in market and other factors , including the impact of hurricanes and other weather-related events . our simple average mill system operating rates for the last three years averaged 94% ( 94 % ) . we own all of our mills. .
condition are valued using a monte carlo model . expected volatility is based on historical volatilities of traded common stock of the company and comparative companies using daily stock prices over the past three years . the expected term is three years and the risk-free interest rate is based on the three-year u.s . treasury rate in effect as of the measurement date . the following table provides the weighted average assumptions used in the monte carlo simulation and the weighted average grant date fair values of psus granted for the years ended december 31: .
what was the minimum grant date fair value per share in the table?
the grant date fair value of psus that vest ratably and have market and/or performance conditions are amortized through expense over the requisite service period using the graded-vesting method . if dividends are paid with respect to shares of the company 2019s common stock before the rsus and psus are distributed , the company credits a liability for the value of the dividends that would have been paid if the rsus and psus were shares of company common stock . when the rsus and psus are distributed , the company pays the participant a lump sum cash payment equal to the value of the dividend equivalents accrued . the company accrued dividend equivalents totaling $ 1 million , less than $ 1 million and $ 1 million to accumulated deficit in the accompanying consolidated statements of changes in shareholders 2019 equity for the years ended december 31 , 2018 , 2017 and 2016 , respectively . employee stock purchase plan the company maintains a nonqualified employee stock purchase plan ( the 201cespp 201d ) through which employee participants may use payroll deductions to acquire company common stock at a discount . prior to february 5 , 2019 , the purchase price of common stock acquired under the espp was the lesser of 90% ( 90 % ) of the fair market value of the common stock at either the beginning or the end of a three -month purchase period . on july 27 , 2018 , the espp was amended , effective february 5 , 2019 , to permit employee participants to acquire company common stock at 85% ( 85 % ) of the fair market value of the common stock at the end of the purchase period . as of december 31 , 2018 , there were 1.9 million shares of common stock reserved for issuance under the espp . the espp is considered compensatory . during the years ended december 31 , 2018 , 2017 and 2016 , the company issued 95 thousand , 93 thousand and 93 thousand shares , respectively , under the espp. .
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: .
using the above listed average exercise price , what were the value of the put options purchased?
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. .
stock performance graph : the graph below shows the cumulative total shareholder return assuming the investment of $ 100 , on december 31 , 2013 , and the reinvestment of dividends thereafter , if any , in the company 2019s common stock versus the standard and poor 2019s s&p 500 retail index ( 201cs&p 500 retail index 201d ) and the standard and poor 2019s s&p 500 index ( 201cs&p 500 201d ) . .
what is the roi of an investment in o 2019reilly automotive inc . from 2013 to 2017?
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entergy arkansas , inc . management's financial discussion and analysis results of operations net income 2004 compared to 2003 net income increased $ 16.2 million due to lower other operation and maintenance expenses , a lower effective income tax rate for 2004 compared to 2003 , and lower interest charges . the increase was partially offset by lower net revenue . 2003 compared to 2002 net income decreased $ 9.6 million due to lower net revenue , higher depreciation and amortization expenses , and a higher effective income tax rate for 2003 compared to 2002 . the decrease was substantially offset by lower other operation and maintenance expenses , higher other income , and lower interest charges . net revenue 2004 compared to 2003 net revenue , which is entergy arkansas' 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. .
what are the deferred fuel cost revisions as a percentage of the decrease in net revenue from 2003 to 2004?
deferred fuel cost revisions includes the difference between the estimated deferred fuel expense and the actual calculation of recoverable fuel expense , which occurs on an annual basis . deferred fuel cost revisions decreased net revenue due to a revised estimate of fuel costs filed for recovery at entergy arkansas in the march 2004 energy cost recovery rider , which reduced net revenue by $ 11.5 million . the remainder of the variance is due to the 2002 energy cost recovery true-up , made in the first quarter of 2003 , which increased net revenue in 2003 . gross operating revenues , fuel and purchased power expenses , and other regulatory credits gross operating revenues increased primarily due to : 2022 an increase of $ 20.7 million in fuel cost recovery revenues due to an increase in the energy cost recovery rider effective april 2004 ( fuel cost recovery revenues are discussed in note 2 to the domestic utility companies and system energy financial statements ) ; 2022 an increase of $ 15.5 million in grand gulf revenues due to an increase in the grand gulf rider effective january 2004 ; 2022 an increase of $ 13.9 million in gross wholesale revenue primarily due to increased sales to affiliated systems ; 2022 an increase of $ 9.5 million due to volume/weather primarily resulting from increased usage during the unbilled sales period , partially offset by the effect of milder weather on billed sales in 2004. .
item 2 . properties we employ a variety of assets in the management and operation of our rail business . our rail network covers 23 states in the western two-thirds of the u.s . our rail network includes 31838 route miles . we own 26009 miles and operate on the remainder pursuant to trackage rights or leases . the following table describes track miles at december 31 , 2013 and 2012 . 2013 2012 .
what is the percent of the owned and operated of the rail network route miles
headquarters building we maintain our headquarters in omaha , nebraska . the facility has 1.2 million square feet of space for approximately 4000 employees and is subject to a financing arrangement . harriman dispatching center the harriman dispatching center ( hdc ) , located in omaha , nebraska , is our primary dispatching facility . it is linked to regional dispatching and locomotive management facilities at various locations along our .
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: .
what is the percent change in energy mississippi's receivables between 2006 and 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. .
devon energy corporation and subsidiaries notes to consolidated financial statements 2013 ( continued ) proved undeveloped reserves the following table presents the changes in devon 2019s total proved undeveloped reserves during 2013 ( in mmboe ) . .
what percentage decrease was there from the 2012 proved undeveloped reserves to 2013 proved undeveloped reserves?
at december 31 , 2013 , devon had 701 mmboe of proved undeveloped reserves . this represents a 17 percent decrease as compared to 2012 and represents 24 percent of total proved reserves . drilling and development activities increased devon 2019s proved undeveloped reserves 95 mmboe and resulted in the conversion of 147 mmboe , or 18 percent , of the 2012 proved undeveloped reserves to proved developed reserves . costs incurred related to the development and conversion of devon 2019s proved undeveloped reserves were $ 1.9 billion for 2013 . additionally , revisions other than price decreased devon 2019s proved undeveloped reserves 78 mmboe primarily due to evaluations of certain u.s . onshore dry-gas areas , which devon does not expect to develop in the next five years . the largest revisions relate to the dry-gas areas in the cana-woodford shale in western oklahoma , carthage in east texas and the barnett shale in north texas . a significant amount of devon 2019s proved undeveloped reserves at the end of 2013 related to its jackfish operations . at december 31 , 2013 and 2012 , devon 2019s jackfish proved undeveloped reserves were 441 mmboe and 429 mmboe , respectively . development schedules for the jackfish reserves are primarily controlled by the need to keep the processing plants at their 35000 barrel daily facility capacity . processing plant capacity is controlled by factors such as total steam processing capacity , steam-oil ratios and air quality discharge permits . as a result , these reserves are classified as proved undeveloped for more than five years . currently , the development schedule for these reserves extends though the year 2031 . price revisions 2013 2013 reserves increased 94 mmboe primarily due to higher gas prices . of this increase , 43 mmboe related to the barnett shale and 19 mmboe related to the rocky mountain area . 2012 2013 reserves decreased 171 mmboe primarily due to lower gas prices . of this decrease , 100 mmboe related to the barnett shale and 25 mmboe related to the rocky mountain area . 2011 2013 reserves decreased 21 mmboe due to lower gas prices and higher oil prices . the higher oil prices increased devon 2019s canadian royalty burden , which reduced devon 2019s oil reserves . revisions other than price total revisions other than price for 2013 , 2012 and 2011 primarily related to devon 2019s evaluation of certain dry gas regions , with the largest revisions being made in the cana-woodford shale , barnett shale and carthage .
performance graph the graph below compares the cumulative total shareholder return on pmi's common stock with the cumulative total return for the same period of pmi's peer group and the s&p 500 index . the graph assumes the investment of $ 100 as of december 31 , 2012 , in pmi common stock ( at prices quoted on the new york stock exchange ) and each of the indices as of the market close and reinvestment of dividends on a quarterly basis . date pmi pmi peer group ( 1 ) s&p 500 index .
what was the percentage cumulative total shareholder return on pmi's common stock for the five years ended december 31 , 2017?
( 1 ) the pmi peer group presented in this graph is the same as that used in the prior year , except reynolds american inc . was removed following the completion of its acquisition by british american tobacco p.l.c . on july 25 , 2017 . the pmi peer group was established based on a review of four characteristics : global presence ; a focus on consumer products ; and net revenues and a market capitalization of a similar size to those of pmi . the review also considered the primary international tobacco companies . as a result of this review , the following companies constitute the pmi peer group : altria group , inc. , anheuser-busch inbev sa/nv , british american tobacco p.l.c. , the coca-cola company , colgate-palmolive co. , diageo plc , heineken n.v. , imperial brands plc , japan tobacco inc. , johnson & johnson , kimberly-clark corporation , the kraft-heinz company , mcdonald's corp. , mondel z international , inc. , nestl e9 s.a. , pepsico , inc. , the procter & gamble company , roche holding ag , and unilever nv and plc . note : figures are rounded to the nearest $ 0.10. .
table of contents stock performance graph * $ 100 invested on 11/17/11 in our stock or 10/31/11 in the relevant index , including reinvestment of dividends . fiscal year ending december 31 , 2015 . ( 1 ) delphi automotive plc ( 2 ) s&p 500 2013 standard & poor 2019s 500 total return index ( 3 ) automotive supplier peer group 2013 russell 3000 auto parts index , including american axle & manufacturing , borgwarner inc. , cooper tire & rubber company , dana holding corp. , delphi automotive plc , dorman products inc. , federal-mogul corp. , ford motor co. , fuel systems solutions inc. , general motors co. , gentex corp. , gentherm inc. , genuine parts co. , johnson controls inc. , lear corp. , lkq corp. , meritor inc. , standard motor products inc. , stoneridge inc. , superior industries international , tenneco inc. , tesla motors inc. , the goodyear tire & rubber co. , tower international inc. , visteon corp. , and wabco holdings inc . company index november 17 , december 31 , december 31 , december 31 , december 31 , december 31 .
what is the difference in total return on delphi automotive plc and the automotive supplier peer group for the five year period ending december 31 2015?
dividends the company has declared and paid cash dividends of $ 0.25 per ordinary share in each quarter of 2014 and 2015 . in addition , in january 2016 , the board of directors increased the annual dividend rate to $ 1.16 per ordinary share , and declared a regular quarterly cash dividend of $ 0.29 per ordinary share , payable on february 29 , 2016 to shareholders of record at the close of business on february 17 , 2016. .