other taxes decreased in 2001 because its utility operations in virginia became subject to state income taxes in lieu of gross receipts taxes effective january 2001 . in addition , dominion recognized higher effective rates for foreign earnings and higher pretax income in relation to non-conventional fuel tax credits realized . dominion energy 2002 2001 2000 ( millions , except per share amounts ) .

Table:
( millions except pershare amounts ) | 2002 | 2001 | 2000
operating revenue | $ 5940 | $ 6144 | $ 4894
operating expenses | 4520 | 4749 | 3939
net income contribution | 770 | 723 | 489
earnings per share contribution | $ 2.72 | $ 2.86 | $ 2.07
electricity supplied* ( million mwhrs ) | 101 | 95 | 83
gas transmission throughput ( bcf ) | 597 | 553 | 567
* amounts presented are for electricity supplied by utility and merchant generation operations .
operating results 2014 2002 dominion energy contributed $ 2.72 per diluted share on net income of $ 770 million for 2002 , a net income increase of $ 47 million and an earnings per share decrease of $ 0.14 over 2001 .
net income for 2002 reflected lower operating revenue ( $ 204 million ) , operating expenses ( $ 229 million ) and other income ( $ 27 million ) .
interest expense and income taxes , which are discussed on a consolidated basis , decreased $ 50 million over 2001 .
the earnings per share decrease reflected share dilution .
regulated electric sales revenue increased $ 179 million .
favorable weather conditions , reflecting increased cooling and heating degree-days , as well as customer growth , are estimated to have contributed $ 133 million and $ 41 million , respectively .
fuel rate recoveries increased approximately $ 65 million for 2002 .
these recoveries are generally offset by increases in elec- tric fuel expense and do not materially affect income .
partially offsetting these increases was a net decrease of $ 60 million due to other factors not separately measurable , such as the impact of economic conditions on customer usage , as well as variations in seasonal rate premiums and discounts .
nonregulated electric sales revenue increased $ 9 million .
sales revenue from dominion 2019s merchant generation fleet decreased $ 21 million , reflecting a $ 201 million decline due to lower prices partially offset by sales from assets acquired and constructed in 2002 and the inclusion of millstone operations for all of 2002 .
revenue from the wholesale marketing of utility generation decreased $ 74 million .
due to the higher demand of utility service territory customers during 2002 , less production from utility plant generation was available for profitable sale in the wholesale market .
revenue from retail energy sales increased $ 71 million , reflecting primarily customer growth over the prior year .
net revenue from dominion 2019s electric trading activities increased $ 33 million , reflecting the effect of favorable price changes on unsettled contracts and higher trading margins .
nonregulated gas sales revenue decreased $ 351 million .
the decrease included a $ 239 million decrease in sales by dominion 2019s field services and retail energy marketing opera- tions , reflecting to a large extent declining prices .
revenue associated with gas trading operations , net of related cost of sales , decreased $ 112 million .
the decrease included $ 70 mil- lion of realized and unrealized losses on the economic hedges of natural gas production by the dominion exploration & pro- duction segment .
as described below under selected information 2014 energy trading activities , sales of natural gas by the dominion exploration & production segment at market prices offset these financial losses , resulting in a range of prices contemplated by dominion 2019s overall risk management strategy .
the remaining $ 42 million decrease was due to unfavorable price changes on unsettled contracts and lower overall trading margins .
those losses were partially offset by contributions from higher trading volumes in gas and oil markets .
gas transportation and storage revenue decreased $ 44 million , primarily reflecting lower rates .
electric fuel and energy purchases expense increased $ 94 million which included an increase of $ 66 million associated with dominion 2019s energy marketing operations that are not sub- ject to cost-based rate regulation and an increase of $ 28 million associated with utility operations .
substantially all of the increase associated with non-regulated energy marketing opera- tions related to higher volumes purchased during the year .
for utility operations , energy costs increased $ 66 million for pur- chases subject to rate recovery , partially offset by a $ 38 million decrease in fuel expenses associated with lower wholesale mar- keting of utility plant generation .
purchased gas expense decreased $ 245 million associated with dominion 2019s field services and retail energy marketing oper- ations .
this decrease reflected approximately $ 162 million asso- ciated with declining prices and $ 83 million associated with lower purchased volumes .
liquids , pipeline capacity and other purchases decreased $ 64 million , primarily reflecting comparably lower levels of rate recoveries of certain costs of transmission operations in the cur- rent year period .
the difference between actual expenses and amounts recovered in the period are deferred pending future rate adjustments .
other operations and maintenance expense decreased $ 14 million , primarily reflecting an $ 18 million decrease in outage costs due to fewer generation unit outages in the current year .
depreciation expense decreased $ 11 million , reflecting decreases in depreciation associated with changes in the esti- mated useful lives of certain electric generation property , par- tially offset by increased depreciation associated with state line and millstone operations .
other income decreased $ 27 million , including a $ 14 mil- lion decrease in net realized investment gains in the millstone 37d o m i n i o n 2019 0 2 a n n u a l r e p o r t .

Question: if the 2003 growth rate is the same as 2002 , what would 2003 gas transmission throughput be in bcf?\\n
Answer: 645
Calculation: divide(597, 553), multiply(#0, 597)