Journal of Canadian Petroleum Technology
Volume 49,
Number 6,
June 2010,
pp. 53-67
Summary
Up-to-date well test analysis in naturally fractured reservoirs is based on
the radial flow model. The radial flow model is only applicable to purely
homogeneous systems and is a long-term solution in general. It cannot provide
complete formation analysis in reservoirs that exhibit anisotropy. This study,
therefore, presents a new method of estimating permeability anisotropy in
naturally fractured reservoirs.
Maximum and minimum permeability are obtained from a single well test. The
maximum permeability is attributed to the large-scale fractures in the system,
while the minimum permeability may be caused by the small-scale fractures
orthogonal to the large-scale fractures. In a situation where the fractures are
oriented in one direction, the minimum permeability will reflect the matrix
permeability. The type of flow path developed (narrow or wide flow path) can
also be predicted. This is useful in predicting the direction of
fluid-flow.
Application was made to four field examples, among which was an interference
test. The interference test was used as a validation process. The results
obtained are in agreement with that of the interference test method of
analysis.
© 2010. Society of Petroleum Engineers
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History
- Original manuscript received:
28 October 2008
- Meeting paper published:
18 June 2008
- Revised manuscript received:
5 April 2010
- Manuscript approved:
8 April 2010
- Published online:
21 June 2010
- Version of record:
1 June 2010
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