Technology Status Report: In Situ Flushing - CLU-IN
Technology Status Report: In Situ Flushing - CLU-IN
Technology Status Report: In Situ Flushing - CLU-IN
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<strong>In</strong> <strong>Situ</strong> <strong>Flushing</strong> Project Summaries<br />
GWRTAC Case Study Database<br />
GWRTAC ID: FLSH0059<br />
Project Name: Fredricksburg, VA Wood Treating Site<br />
City: Fredricksburg State/Province: VA<br />
Primary GWRTAC Personal<br />
Communication Source<br />
(Name/Organization):<br />
Project Summary:<br />
None<br />
None<br />
<strong>Report</strong>(s)/Publication(s) (GWRTAC Source):<br />
Rice University, 1997: <strong>Technology</strong> Practices Manual for Surfactants and Cosolvents, Rice<br />
University, 6100 Main Street, Houston, TX 77005-1892, February 1997<br />
The following was quoted from Rice University, 1997: <strong>Technology</strong> Practices Manual for<br />
Surfactants and Cosolvents, Rice University, 6100 Main Street, Houston, TX 77005-1892, February<br />
1997:<br />
"<strong>In</strong> 1990, a combination of an alkaline agent, surfactant, and polymer were used to recover<br />
creosote-based wood-treating oils from soils at a wood-treating site in Fredricksburg, Virginia. Soils<br />
of concern consisted of a clay-silt alluvium. Characteristics of the oil included a density of 1.03<br />
g/cm3and a viscosity of 50 centipoise.<br />
The site geology was complex, with clay lenses on which creosote based oil was perched.<br />
Hydraulic conductivity was low and varied as the soil composition changed. Soil composition<br />
resulted in varying oil saturations that changed with time as perched creosote moved off of clay<br />
lenses.<br />
A laboratory program was undertaken to define the optimum chemical system to remove the oil. A<br />
mobilization mechanism was selected. <strong>In</strong>terfacial tensions were lowered to ultra low values with a<br />
combination of alkali and surfactant. The solution selected for injection was 0.5 wt% Na2 CO3 plus<br />
0.1 wt% Makon-10 (nonyl phenol with 10 moles ethylene oxide) and 1,500 mg/L xanthan gum.<br />
Polymer was added to the injected solution to improve contact and displacement efficiencies.<br />
Mobility ratio for water displacing creosote was adverse indicating need for polymer.<br />
Existing wells were used for the field demonstration. A single vertical injection well and a single<br />
vertical production well were used. Spacing between the wells was 6 feet. <strong>In</strong>jection of the chemical<br />
solution was the limiting factor. <strong>In</strong>jection of the chemical solution was attempted for approximately<br />
1 month with minimal success.<br />
Oil recovery as a result of the alkaline-surfactant-polymer solution was low for two reasons. Low<br />
chemical solution injectivity reduced the planned injection volumes to less effective amounts and<br />
the creosote saturation in the area selected was low as a result of perched material moving off clay<br />
lenses. The pilot project was not expanded.<br />
The failure of the application points out the critical need for accurate and reliable site assessment<br />
Ground-Water Remediation Technologies Analysis Center<br />
Operated by Concurrent Technologies Corporation<br />
Appendix - Page 119 of 164<br />
Copyright GWRTAC 1998<br />
Revision 1<br />
Tuesday, November 17, 1998