as of december 31 2013 what was the percentage of the proved undeveloped reserves in the us
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 ) . .

|  | U.S. | Canada | Total |
| :--- | :--- | :--- | :--- |
| Proved undeveloped reserves as of December 31, 2013 | 258 | 443 | 701 |
| Extensions and discoveries | 153 | 8 | 161 |
| Revisions due to prices | (1) | (34) | (35) |
| Revisions other than price | (61) | 18 | (43) |
| Sale of reserves | (4) | (2) | (6) |
| Conversion to proved developed reserves | (40) | (49) | (89) |
| 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. .

proved_undeveloped_reserves_2013 = 258
proved_undeveloped_reserves_total = 701
percent_proved_undeveloped_reserves_2013 = proved_undeveloped_reserves_2013 / proved_undeveloped_reserves_total
answer = percent_proved_undeveloped_reserves_2013 * 100