Abstract
It is possible to engineer and control the extents of the stimulation rock volume for hydraulic fracturing. Currently, available tools and methods intended to accomplish this task focus on optimizing injection fluid properties, utilizing existing rock stress boundaries, controlling stimulation intervals in the injection well, and manipulating injection pressures and rates. What if it were possible to control hydraulic fracture extents more directly than these methods do and to have confirmation of these extents in the subsurface? For this, we propose a ‘fracture caging’ concept where an array of injection wells and production wells are drilled prior to stimulation as a means to identify and control the extent of a stimulated zone. Positive identification of stimulation extents occurs by monitoring production well pressures and flow rates. Control of fracture extents occurs by control of the production well pressures and arrangement of production wells so as to contain an intended stimulated zone. In this study, we present the fracture caging concept and validate it with laboratory experiments. Numerical modelling with LLNL’s GEOS code is used to predict the effectiveness of the fracture caging concept as it applies to the SIGMA-V (EGS Collab) geothermal energy research field site.
| Original language | English (US) |
|---|---|
| State | Published - Jan 1 2018 |
| Event | 52nd U.S. Rock Mechanics/Geomechanics Symposium - Seattle, United States Duration: Jun 17 2018 → Jun 20 2018 |
Other
| Other | 52nd U.S. Rock Mechanics/Geomechanics Symposium |
|---|---|
| Country | United States |
| City | Seattle |
| Period | 6/17/18 → 6/20/18 |
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All Science Journal Classification (ASJC) codes
- Geophysics
- Geochemistry and Petrology
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Laboratory validation of fracture caging for hydraulic fracture control. / EGS Collab Team.
2018. Paper presented at 52nd U.S. Rock Mechanics/Geomechanics Symposium, Seattle, United States.Research output: Contribution to conference › Paper
TY - CONF
T1 - Laboratory validation of fracture caging for hydraulic fracture control
AU - EGS Collab Team
AU - Frash, L. P.
AU - Arora, K.
AU - Gan, Y.
AU - Lu, M.
AU - Gutierrez, M.
AU - Fu, P.
AU - Morris, J.
AU - Hampton, J.
AU - Ajo-Franklin, J.
AU - Bauer, S. J.
AU - Baumgartner, T.
AU - Beckers, K.
AU - Blankenship, D.
AU - Bonneville, A.
AU - Boyd, L.
AU - Brown, S. T.
AU - Burghardt, J. A.
AU - Chen, T.
AU - Chen, Y.
AU - Condon, K.
AU - Cook, P. J.
AU - Dobson, P. F.
AU - Doe, T.
AU - Doughty, C. A.
AU - Elsworth, Derek
AU - Feldman, J.
AU - Foris, A.
AU - Frash, L. P.
AU - Frone, Z.
AU - Fu, P.
AU - Gao, K.
AU - Ghassemi, A.
AU - Gudmundsdottir, H.
AU - Guglielmi, Y.
AU - Guthrie, G.
AU - Haimson, B.
AU - Hawkins, A.
AU - Heise, J.
AU - Herrick, C. G.
AU - Horn, M.
AU - Horne, R. N.
AU - Horner, J.
AU - Hu, M.
AU - Huang, H.
AU - Huang, L.
AU - Im, K.
AU - Ingraham, M.
AU - Johnson, T. C.
AU - Johnston, B.
AU - Marone, Chris J.
PY - 2018/1/1
Y1 - 2018/1/1
N2 - It is possible to engineer and control the extents of the stimulation rock volume for hydraulic fracturing. Currently, available tools and methods intended to accomplish this task focus on optimizing injection fluid properties, utilizing existing rock stress boundaries, controlling stimulation intervals in the injection well, and manipulating injection pressures and rates. What if it were possible to control hydraulic fracture extents more directly than these methods do and to have confirmation of these extents in the subsurface? For this, we propose a ‘fracture caging’ concept where an array of injection wells and production wells are drilled prior to stimulation as a means to identify and control the extent of a stimulated zone. Positive identification of stimulation extents occurs by monitoring production well pressures and flow rates. Control of fracture extents occurs by control of the production well pressures and arrangement of production wells so as to contain an intended stimulated zone. In this study, we present the fracture caging concept and validate it with laboratory experiments. Numerical modelling with LLNL’s GEOS code is used to predict the effectiveness of the fracture caging concept as it applies to the SIGMA-V (EGS Collab) geothermal energy research field site.
AB - It is possible to engineer and control the extents of the stimulation rock volume for hydraulic fracturing. Currently, available tools and methods intended to accomplish this task focus on optimizing injection fluid properties, utilizing existing rock stress boundaries, controlling stimulation intervals in the injection well, and manipulating injection pressures and rates. What if it were possible to control hydraulic fracture extents more directly than these methods do and to have confirmation of these extents in the subsurface? For this, we propose a ‘fracture caging’ concept where an array of injection wells and production wells are drilled prior to stimulation as a means to identify and control the extent of a stimulated zone. Positive identification of stimulation extents occurs by monitoring production well pressures and flow rates. Control of fracture extents occurs by control of the production well pressures and arrangement of production wells so as to contain an intended stimulated zone. In this study, we present the fracture caging concept and validate it with laboratory experiments. Numerical modelling with LLNL’s GEOS code is used to predict the effectiveness of the fracture caging concept as it applies to the SIGMA-V (EGS Collab) geothermal energy research field site.
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M3 - Paper
ER -