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 ( 1 )
-34 ( 34 )
-35 ( 35 )
revisions other than price
-61 ( 61 )
18
-43 ( 43 )
sale of reserves
-4 ( 4 )
-2 ( 2 )
-6 ( 6 )
conversion to proved developed reserves
-40 ( 40 )
-49 ( 49 )
-89 ( 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. .

Question: what percentage of total proved undeveloped resources as of dec 31 , 2014 does extensions and discoveries and proved undeveloped resources as of dec 31 , 2013 account for?
Answer: 125.1%

Question: what was the percentage reduction of the proved undeveloped reserves from 2013 to 2014
Answer: -1.7%