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Geochemical modeling of CO2 storage in deep reservoirs: The Weyburn Project (Canada) case study
Author(s)
Language
English
Obiettivo Specifico
2.4. TTC - Laboratori di geochimica dei fluidi
Status
Published
JCR Journal
JCR Journal
Peer review journal
Yes
Title of the book
Issue/vol(year)
/265(2009)
Pages (printed)
181-197
Issued date
2009
Abstract
Geological storage is presently one of the most promising options for reducing anthropogenic emissions of
CO2. Among the several projects investigating the fate of CO2 stored at depth, the EnCana's CO2 injection EOR
(Enhancing Oil Recovery) project at Weyburn (Saskatchewan, Canada) is the most important oil production
development that hosts an international monitoring project. In the Weyburn EOR Project CO2 is used to
increase recovery of heavy oil from the Midale Beds, a Mississippian reservoir consisting of shallow marine
carbonate, where about 3 billions standard m3 of supercritical CO2 have been injected since 2000 with an
injection rate of 5000 ton/day.
In this work the available dataset (bulk mineralogy of the reservoir, gas-cap composition and selected preand
post-CO2 injection water samples) provided by the International Energy Agency Weyburn CO2 Monitoring
& Storage Project has been used in order to:
i) reconstruct the pre-injection reservoir chemical composition (including pH and the boundary conditions
at 62 °C and 15 MPa);
ii) assess the evolution of the reservoir subjected to CO2 injection and predict dissolution/precipitation
processes of the Weyburn brines over 100 years after injection;
iii) validate the short-term (September 2000–2003) evolution of the in situ reservoir fluids due to the CO2
injection, by comparing the surface analytical data with the composition of the computed depressurized brines.
To achieve these goals the PRHEEQC (V2.14) Software Package was used with both modified thermodynamic
database and correction for supercritical CO2 fugacity. The oil–gas–water interaction and the non-ideality of
the gas phase (with exception of CO2) were not considered in the numerical simulations. Despite intrinsic
limitations and uncertainties of geochemical modeling, the main results can be summarized, as follows: 1)
the calculated pre-injection chemical composition of the Midale Beds brine is consistent with the analytical
data of the waters collected in 2000 (baseline survey), 2) the main reservoir reactions (CO2 and carbonate
dissolution) take place within the first year of simulation, 3) the temporal evolution of the chemical features
of the fluids in the Weyburn reservoir suggests that CO2 can safely be stored by solubility (as CO2(aq)) and
mineral trapping (via dawsonite precipitation). The short-term validation performed by calculating chemical
composition of the reservoir fluids (corrected for surface conditions) after the simulation of 3 years of CO2
injection is consistent (error ≤5%) with the analytical data of the wellhead water samples collected in 2003,
with the exception of Ca and Mg (error N90%), likely due to complexation effect of carboxilic acid.
CO2. Among the several projects investigating the fate of CO2 stored at depth, the EnCana's CO2 injection EOR
(Enhancing Oil Recovery) project at Weyburn (Saskatchewan, Canada) is the most important oil production
development that hosts an international monitoring project. In the Weyburn EOR Project CO2 is used to
increase recovery of heavy oil from the Midale Beds, a Mississippian reservoir consisting of shallow marine
carbonate, where about 3 billions standard m3 of supercritical CO2 have been injected since 2000 with an
injection rate of 5000 ton/day.
In this work the available dataset (bulk mineralogy of the reservoir, gas-cap composition and selected preand
post-CO2 injection water samples) provided by the International Energy Agency Weyburn CO2 Monitoring
& Storage Project has been used in order to:
i) reconstruct the pre-injection reservoir chemical composition (including pH and the boundary conditions
at 62 °C and 15 MPa);
ii) assess the evolution of the reservoir subjected to CO2 injection and predict dissolution/precipitation
processes of the Weyburn brines over 100 years after injection;
iii) validate the short-term (September 2000–2003) evolution of the in situ reservoir fluids due to the CO2
injection, by comparing the surface analytical data with the composition of the computed depressurized brines.
To achieve these goals the PRHEEQC (V2.14) Software Package was used with both modified thermodynamic
database and correction for supercritical CO2 fugacity. The oil–gas–water interaction and the non-ideality of
the gas phase (with exception of CO2) were not considered in the numerical simulations. Despite intrinsic
limitations and uncertainties of geochemical modeling, the main results can be summarized, as follows: 1)
the calculated pre-injection chemical composition of the Midale Beds brine is consistent with the analytical
data of the waters collected in 2000 (baseline survey), 2) the main reservoir reactions (CO2 and carbonate
dissolution) take place within the first year of simulation, 3) the temporal evolution of the chemical features
of the fluids in the Weyburn reservoir suggests that CO2 can safely be stored by solubility (as CO2(aq)) and
mineral trapping (via dawsonite precipitation). The short-term validation performed by calculating chemical
composition of the reservoir fluids (corrected for surface conditions) after the simulation of 3 years of CO2
injection is consistent (error ≤5%) with the analytical data of the wellhead water samples collected in 2003,
with the exception of Ca and Mg (error N90%), likely due to complexation effect of carboxilic acid.
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