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« Back to Application Overview |
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Conformance Control
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APPLICATIONS » A significant problem in most mature waterflood operations is poor oil recovery of the Original Oil In Place (OOIP), even after decades of water injection. However, due to the heterogeneous nature of most formations, waterflood operations quite often have poor sweep efficiency. Often, most of the injection brine enters and travels through limited portions of the reservoir which have the highest permeability in the formation matrix and in any fractures. These high conductivity portions of the reservoir are called thief zones and will capture a significant portion of injection water. As a result the waterflood largely will bypass those sections or layers of the reservoir having higher oil saturations holding the greater amounts of recoverable oil.
ChemEOR has developed Cerogel PPG products to block these high flow channels and improve the conformance control. ChemEOR is also developing a unique PolyFlood T-85 polymer chemistry to facilitate auto-gellation for in-depth fluid diversion.
- Cerogel PPG » Preformed Particle Gel for general conformance control
- Polyflood T85 » Self-Thickening Polymer for in-depth fluid diversion
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Cerogel PPG »
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Cerogel PPG is a class of elastic gel particles (< 1 mm) that swell quickly to become large soft gel particles when added into water. It can be injected as a suspension in water into an injection well. The soft gel particles selectively plug these high perm “thief zones” in the near wellbore region. Then the injection water post-PPG treatment is forced into previously unswept zones in the reservoir. This improved conformance control treatment increases oil production and decreases WOR. Customized PPG products can be applied in high temerpature and high salinity conditions. |
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PolyFlood T-85 » |
Single composition product -- an advantage over multi-component systems that require an in-situ reaction to work. Add T-85 to injection water for a designed volume of treatment. The solution then thickens and increases viscosity in-situ; the timing of the fluid change controls depth of treatment. The extent of the viscosity increase may be even to a gel-like state. This plugs off the high flow channels and so the injection water following this treatment is diverted into the lower permeability areas that still contain high oil saturation. The end result is an increase in oil and decrease in water production. |
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