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Did you know you could use DST data to analyze basins or regions to identify prospect leads?
First, you know that you have a valid DST to use in your search for prospects if the ISIP and FSIP are close to equal, indicating the reservoir is not depleted or limited. Initial hydrostatic and final hydrostatic pressures are close to equal if there was no significant mud loss during the test. Lastly, you have a valid DST if the two hydrostatic pressures are greater than the shut-in pressures. We also know that large recoveries of fluids and/or gas are indicative of good permeability to flow. To determine areas of good permeability, you can calculate the ratio of final flowing pressure to final shut-in pressure, with higher ratios indicating higher permeability. Looking at any DST data anywhere in the world, you will see that FP/SIP ratios with fluid recoveries are usually 75% higher than FP/SIP ratios without fluid recovery, which indicates permeability. A high FP/SIP ratio with little or no fluid recovery usually indicates near wellbore damage. Remember that the FP/SIP ratios always remain the same whether damage exists or not, because, according to Darcy's Law, flowrate is proportional to the permeability at the wellbore. Just remember these simple relationships when evaluating DST data:
High k = FP is closer to SIP
Low k = FP is much smaller than SIP
FSIP < ISIP is indicative of depletion or limited reservoir
Back to October 2003 Newsletter
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