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 2014 ( in mmboe ) . .

Row 1: , u.s ., canada, total
Row 2: proved undeveloped reserves as of december 31 2013, 258, 443, 701
Row 3: extensions and discoveries, 153, 8, 161
Row 4: revisions due to prices, -1 ( 1 ), -34 ( 34 ), -35 ( 35 )
Row 5: revisions other than price, -61 ( 61 ), 18, -43 ( 43 )
Row 6: sale of reserves, -4 ( 4 ), -2 ( 2 ), -6 ( 6 )
Row 7: conversion to proved developed reserves, -40 ( 40 ), -49 ( 49 ), -89 ( 89 )
Row 8: proved undeveloped reserves as of december 31 2014, 305, 384, 689

at december 31 , 2014 , devon had 689 mmboe of proved undeveloped reserves . this represents a 2 percent decrease as compared to 2013 and represents 25 percent of total proved reserves . drilling and development activities increased devon 2019s proved undeveloped reserves 161 mmboe and resulted in the conversion of 89 mmboe , or 13 percent , of the 2013 proved undeveloped reserves to proved developed reserves . costs incurred related to the development and conversion of devon 2019s proved undeveloped reserves were approximately $ 1.0 billion for 2014 . additionally , revisions other than price decreased devon 2019s proved undeveloped reserves 43 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 , which were approximately 69 mmboe , relate to the dry-gas areas in the barnett shale in north texas . a significant amount of devon 2019s proved undeveloped reserves at the end of 2014 related to its jackfish operations . at december 31 , 2014 and 2013 , devon 2019s jackfish proved undeveloped reserves were 384 mmboe and 441 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 and steam-oil ratios . furthermore , development of these projects involves the up-front construction of steam injection/distribution and bitumen processing facilities . due to the large up-front capital investments and large reserves required to provide economic returns , the project conditions meet the specific circumstances requiring a period greater than 5 years for conversion to developed reserves . 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 2014 2013 reserves increased 9 mmboe primarily due to higher gas prices in the barnett shale and the anadarko basin , partially offset by higher bitumen prices , which result in lower after-royalty volumes , in canada . 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. .

Question: what was the percentage reduction of the proved undeveloped reserves from 2013 to 2014
Program: subtract(689, 701), divide(#0, 701)
Answer: -0.01712