rm&t segment we do not attempt to qualify commodity derivative instruments used in our rm&t operations for hedge accounting . as a result , we recognize all changes in the fair value of derivatives used in our rm&t operations in income , although most of these derivatives have an underlying physical commodity transaction . generally , derivative losses occur when market prices increase , which are offset by gains on the underlying physical commodity transactions . conversely , derivative gains occur when market prices decrease , which are offset by losses on the underlying physical commodity transactions . derivative gains or losses included in rm&t segment income for each of the last three years are summarized in the following table : strategy ( in millions ) 2004 2003 2002 .
included in the derivative loss for 2004 noted in the above table for the 2018 2018protect crack spread values 2019 2019 strategy was a gain due to changes in the fair value of crack-spread derivatives that will expire throughout 2005 . what was the loss without benefit of this gain?
during 2004 , using derivative instruments map sold crack spreads forward through the fourth quarter 2005 at values higher than the company thought sustainable in the actual months these contracts expire . included in the $ 76 million derivative loss for 2004 noted in the above table for the 2018 2018protect crack spread values 2019 2019 strategy was approximately an $ 8 million gain due to changes in the fair value of crack-spread derivatives that will expire throughout 2005 . in addition , natural gas options are in place to manage the price risk associated with approximately 41 percent of the first quarter 2005 anticipated natural gas purchases for refinery use . ig segment we have used derivative instruments to convert the fixed price of a long-term gas sales contract to market prices . the underlying physical contract is for a specified annual quantity of gas and matures in 2008 . similarly , we will use derivative instruments to convert shorter term ( typically less than a year ) fixed price contracts to market prices in our ongoing purchase for resale activity ; and to hedge purchased gas injected into storage for subsequent resale . derivative gains included in ig segment income were $ 17 million in 2004 , compared to gains of $ 19 million in 2003 and losses of $ 8 million in 2002 . trading activity in the ig segment resulted in losses of $ 2 million in 2004 , compared to losses of $ 7 million in 2003 and gains of $ 4 million in 2002 and have been included in the aforementioned amounts . other commodity risk we are impacted by basis risk , caused by factors that affect the relationship between commodity futures prices reflected in derivative commodity instruments and the cash market price of the underlying commodity . natural gas transaction prices are frequently based on industry reference prices that may vary from prices experienced in local markets . for example , new york mercantile exchange ( 2018 2018nymex 2019 2019 ) contracts for natural gas are priced at louisiana 2019s henry hub , while the underlying quantities of natural gas may be produced and sold in the western united states at prices that do not move in strict correlation with nymex prices . if commodity price changes in one region are not reflected in other regions , derivative commodity instruments may no longer provide the expected hedge , resulting in increased exposure to basis risk . these regional price differences could yield favorable or unfavorable results . otc transactions are being used to manage exposure to a portion of basis risk . we are impacted by liquidity risk , caused by timing delays in liquidating contract positions due to a potential inability to identify a counterparty willing to accept an offsetting position . due to the large number of active participants , liquidity risk exposure is relatively low for exchange-traded transactions. .