whpthomas/finqa-parquet huggingface dataset:
12 . brokerage receivables and brokerage payables citi has receivables and payables for financial instruments sold to and purchased from brokers , dealers and customers , which arise in the ordinary course of business . citi is exposed to risk of loss from the inability of brokers , dealers or customers to pay for purchases or to deliver the financial instruments sold , in which case citi would have to sell or purchase the financial instruments at prevailing market prices . credit risk is reduced to the extent that an exchange or clearing organization acts as a counterparty to the transaction and replaces the broker , dealer or customer in question . citi seeks to protect itself from the risks associated with customer activities by requiring customers to maintain margin collateral in compliance with regulatory and internal guidelines . margin levels are monitored daily , and customers deposit additional collateral as required . where customers cannot meet collateral requirements , citi may liquidate sufficient underlying financial instruments to bring the customer into compliance with the required margin level . exposure to credit risk is impacted by market volatility , which may impair the ability of clients to satisfy their obligations to citi . credit limits are established and closely monitored for customers and for brokers and dealers engaged in forwards , futures and other transactions deemed to be credit sensitive . brokerage receivables and brokerage payables consisted of the following: .
what was the ratio of the total brokerage payable to the total brokerage receivables in 2016
payables to brokers , dealers , and clearing organizations 19915 18069 total brokerage payables ( 1 ) $ 57152 $ 53722 ( 1 ) includes brokerage receivables and payables recorded by citi broker- dealer entities that are accounted for in accordance with the aicpa accounting guide for brokers and dealers in securities as codified in asc 940-320. .
other operating/performance and financial statistics we report key railroad performance measures weekly to the association of american railroads ( aar ) , including carloads , average daily inventory of rail cars on our system , average train speed , and average terminal dwell time . we provide this data on our website at www.up.com/investors/reports/index.shtml . operating/performance statistics included in the table below are railroad performance measures reported to the aar : 2008 2007 2006 % (  % ) change 2008 v 2007 % (  % ) change 2007 v 2006 .
based on the operating/performance statistics what was the average operating ratio from 2006 to 2008
average train speed 2013 average train speed is calculated by dividing train miles by hours operated on our main lines between terminals . ongoing network management initiatives , productivity improvements , and lower volume levels contributed to 8% ( 8 % ) and 2% ( 2 % ) improvements in average train speed in 2008 and 2007 , respectively . average terminal dwell time 2013 average terminal dwell time is the average time that a rail car spends at our terminals . lower average terminal dwell time improves asset utilization and service . average terminal dwell time improved 1% ( 1 % ) and 8% ( 8 % ) in 2008 and 2007 , respectively . lower volumes combined with initiatives to more timely deliver rail cars to our interchange partners and customers improved dwell time in both periods . gross and revenue ton-miles 2013 gross ton-miles are calculated by multiplying the weight of loaded and empty freight cars by the number of miles hauled . revenue ton-miles are calculated by multiplying the weight of freight by the number of tariff miles . gross ton-miles decreased 3% ( 3 % ) , while revenue ton-miles were flat in 2008 compared to 2007 with commodity mix changes ( notably autos and coal ) explaining the variance in year over year growth between the two metrics . in 2007 , revenue ton-miles declined 1% ( 1 % ) in relation to the 1% ( 1 % ) reduction in carloadings compared to 2006 . gross ton-miles decreased 2% ( 2 % ) in 2007 driven by a mix shift in freight shipments . operating ratio 2013 operating ratio is defined as our operating expenses as a percentage of operating revenue . our operating ratios improved 2.0 points to 77.3% ( 77.3 % ) in 2008 and 2.2 points to 79.3% ( 79.3 % ) in 2007 . price increases , fuel cost recoveries , network management initiatives , and improved productivity more than offset the impact of higher fuel prices . employees 2013 productivity initiatives and lower volumes reduced employee levels throughout the company in 2008 versus 2007 . fewer train and engine personnel due to improved network productivity and 5% ( 5 % ) lower volume drove the change while productivity initiatives within the support organizations also contributed to a lower full-time equivalent force level . lower employee levels in 2007 versus 2006 .
the aes corporation notes to consolidated financial statements 2014 ( continued ) december 31 , 2010 , 2009 , and 2008 ( 3 ) multilateral loans include loans funded and guaranteed by bilaterals , multilaterals , development banks and other similar institutions . ( 4 ) non-recourse debt of $ 708 million as of december 31 , 2009 was excluded from non-recourse debt and included in current and long-term liabilities of held for sale and discontinued businesses in the accompanying consolidated balance sheets . non-recourse debt as of december 31 , 2010 is scheduled to reach maturity as set forth in the table below : december 31 , annual maturities ( in millions ) .
what percentage of total non-recourse debt as of december 31 , 2010 is due in 2012?
as of december 31 , 2010 , aes subsidiaries with facilities under construction had a total of approximately $ 432 million of committed but unused credit facilities available to fund construction and other related costs . excluding these facilities under construction , aes subsidiaries had approximately $ 893 million in a number of available but unused committed revolving credit lines to support their working capital , debt service reserves and other business needs . these credit lines can be used in one or more of the following ways : solely for borrowings ; solely for letters of credit ; or a combination of these uses . the weighted average interest rate on borrowings from these facilities was 3.24% ( 3.24 % ) at december 31 , 2010 . non-recourse debt covenants , restrictions and defaults the terms of the company 2019s non-recourse debt include certain financial and non-financial covenants . these covenants are limited to subsidiary activity and vary among the subsidiaries . these covenants may include but are not limited to maintenance of certain reserves , minimum levels of working capital and limitations on incurring additional indebtedness . compliance with certain covenants may not be objectively determinable . as of december 31 , 2010 and 2009 , approximately $ 803 million and $ 653 million , respectively , of restricted cash was maintained in accordance with certain covenants of the non-recourse debt agreements , and these amounts were included within 201crestricted cash 201d and 201cdebt service reserves and other deposits 201d in the accompanying consolidated balance sheets . various lender and governmental provisions restrict the ability of certain of the company 2019s subsidiaries to transfer their net assets to the parent company . such restricted net assets of subsidiaries amounted to approximately $ 5.4 billion at december 31 , 2010. .
notes to the consolidated financial statements union pacific corporation and subsidiary companies for purposes of this report , unless the context otherwise requires , all references herein to the 201ccorporation 201d , 201cupc 201d , 201cwe 201d , 201cus 201d , and 201cour 201d mean union pacific corporation and its subsidiaries , including union pacific railroad company , which will be separately referred to herein as 201cuprr 201d or the 201crailroad 201d . 1 . nature of operations and significant accounting policies operations and segmentation 2013 we are a class i railroad that operates in the united states . we have 32012 route miles , linking pacific coast and gulf coast ports with the midwest and eastern united states gateways and providing several corridors to key mexican gateways . we serve the western two- thirds of the country and maintain coordinated schedules with other rail carriers for the handling of freight to and from the atlantic coast , the pacific coast , the southeast , the southwest , canada , and mexico . export and import traffic is moved through gulf coast and pacific coast ports and across the mexican and canadian borders . the railroad , along with its subsidiaries and rail affiliates , is our one reportable operating segment . although revenues are analyzed by commodity group , we analyze the net financial results of the railroad as one segment due to the integrated nature of our rail network . the following table provides revenue by commodity group : millions of dollars 2008 2007 2006 .
in 2008 what was the percent of the total freight revenues that was related to agricultural
basis of presentation 2013 certain prior year amounts have been reclassified to conform to the current period financial statement presentation . the reclassifications include reporting freight revenues instead of commodity revenues . the amounts reclassified from freight revenues to other revenues totaled $ 30 million and $ 71 million for the years ended december 31 , 2007 , and december 31 , 2006 , respectively . in addition , we modified our operating expense categories to report fuel used in railroad operations as a stand-alone category , to combine purchased services and materials into one line , and to reclassify certain other expenses among operating expense categories . these reclassifications had no impact on previously reported operating revenues , total operating expenses , operating income or net income . significant accounting policies principles of consolidation 2013 the consolidated financial statements include the accounts of union pacific corporation and all of its subsidiaries . investments in affiliated companies ( 20% ( 20 % ) to 50% ( 50 % ) owned ) are accounted for using the equity method of accounting . all significant intercompany transactions are eliminated . the corporation evaluates its less than majority-owned investments for consolidation .
course of business , we actively manage our exposure to these market risks by entering into various hedging transactions , authorized under established policies that place clear controls on these activities . the counterparties in these transactions are generally highly rated institutions . we establish credit limits for each counterparty . our hedging transactions include but are not limited to a variety of derivative financial instruments . for information on interest rate , foreign exchange , commodity price , and equity instrument risk , please see note 7 to the consolidated financial statements in item 8 of this report . value at risk the estimates in the table below are intended to measure the maximum potential fair value we could lose in one day from adverse changes in market interest rates , foreign exchange rates , commodity prices , and equity prices under normal market conditions . a monte carlo value-at-risk ( var ) methodology was used to quantify the market risk for our exposures . the models assumed normal market conditions and used a 95 percent confidence level . the var calculation used historical interest and foreign exchange rates , and commodity and equity prices from the past year to estimate the potential volatility and correlation of these rates in the future . the market data were drawn from the riskmetrics 2122 data set . the calculations are not intended to represent actual losses in fair value that we expect to incur . further , since the hedging instrument ( the derivative ) inversely correlates with the underlying exposure , we would expect that any loss or gain in the fair value of our derivatives would be generally offset by an increase or decrease in the fair value of the underlying exposure . the positions included in the calculations were : debt ; investments ; interest rate swaps ; foreign exchange forwards ; commodity swaps , futures , and options ; and equity instruments . the calculations do not include the underlying foreign exchange and commodities or equity-related positions that are offset by these market-risk-sensitive instruments . the table below presents the estimated maximum potential var arising from a one-day loss in fair value for our interest rate , foreign currency , commodity , and equity market-risk-sensitive instruments outstanding as of may 27 , 2018 and may 28 , 2017 , and the average fair value impact during the year ended may 27 , 2018. .
what is the total fair value impact for all instruments as of may 27 , 2018?
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part i item 1 entergy corporation , utility operating companies , and system energy louisiana parishes in which it holds non-exclusive franchises . entergy louisiana's electric franchises expire during 2009-2036 . entergy mississippi has received from the mpsc certificates of public convenience and necessity to provide electric service to areas within 45 counties , including a number of municipalities , in western mississippi . under mississippi statutory law , such certificates are exclusive . entergy mississippi may continue to serve in such municipalities upon payment of a statutory franchise fee , regardless of whether an original municipal franchise is still in existence . entergy new orleans provides electric and gas service in the city of new orleans pursuant to city ordinances ( except electric service in algiers , which is provided by entergy louisiana ) . these ordinances contain a continuing option for the city of new orleans to purchase entergy new orleans' electric and gas utility properties . entergy texas holds a certificate of convenience and necessity from the puct to provide electric service to areas within approximately 24 counties in eastern texas , and holds non-exclusive franchises to provide electric service in approximately 65 incorporated municipalities . entergy texas typically is granted 50-year franchises . entergy texas' electric franchises expire during 2009-2045 . the business of system energy is limited to wholesale power sales . it has no distribution franchises . property and other generation resources generating stations the total capability of the generating stations owned and leased by the utility operating companies and system energy as of december 31 , 2008 , is indicated below: .
what portion of the total properties operated by entergy corporation are used by gas/oil stations?
( 1 ) "owned and leased capability" is the dependable load carrying capability as demonstrated under actual operating conditions based on the primary fuel ( assuming no curtailments ) that each station was designed to utilize . the entergy system's load and capacity projections are reviewed periodically to assess the need and timing for additional generating capacity and interconnections . these reviews consider existing and projected demand , the availability and price of power , the location of new load , and the economy . summer peak load in the entergy system service territory has averaged 21039 mw from 2002-2008 . due to changing use patterns , peak load growth has nearly flattened while annual energy use continues to grow . in the 2002 time period , the entergy system's long-term capacity resources , allowing for an adequate reserve margin , were approximately 3000 mw less than the total capacity required for peak period demands . in this time period entergy met its capacity shortages almost entirely through short-term power purchases in the wholesale spot market . in the fall of 2002 , the entergy system began a program to add new resources to its existing generation portfolio and began a process of issuing .
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 s&p500 from 2013 to 2017?
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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 ) . .
as of december 31 2013 what was the percent of the proved undeveloped reserves in canada
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 .
equity compensation plan information the following table presents the equity securities available for issuance under our equity compensation plans as of december 31 , 2018 . equity compensation plan information plan category number of securities to be issued upon exercise of outstanding options , warrants and rights ( 1 ) weighted-average exercise price of outstanding options , warrants and rights number of securities remaining available for future issuance under equity compensation plans ( excluding securities reflected in column ( a ) ) ( a ) ( b ) ( c ) equity compensation plans approved by security holders 399165 $ 0.00 3995600 equity compensation plans not approved by security holders ( 2 ) 2014 2014 2014 .
as of december 312018 what was the total number of number of securities of the equity compensation plans approved by security holders
( 1 ) includes grants made under the huntington ingalls industries , inc . 2012 long-term incentive stock plan ( the "2012 plan" ) , which was approved by our stockholders on may 2 , 2012 , and the huntington ingalls industries , inc . 2011 long-term incentive stock plan ( the "2011 plan" ) , which was approved by the sole stockholder of hii prior to its spin-off from northrop grumman corporation . of these shares , 27123 were stock rights granted under the 2011 plan . in addition , this number includes 31697 stock rights , 5051 restricted stock rights , and 335293 restricted performance stock rights granted under the 2012 plan , assuming target performance achievement . ( 2 ) there are no awards made under plans not approved by security holders . item 13 . certain relationships and related transactions , and director independence information as to certain relationships and related transactions and director independence will be incorporated herein by reference to the proxy statement for our 2019 annual meeting of stockholders , to be filed within 120 days after the end of the company 2019s fiscal year . item 14 . principal accountant fees and services information as to principal accountant fees and services will be incorporated herein by reference to the proxy statement for our 2019 annual meeting of stockholders , to be filed within 120 days after the end of the company 2019s fiscal year. .
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: .
for option expiration dates in 2009 , what was the average option contract volumes ( barrels per day ) for put options purchased and \\ncall options sold?
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. .