PNNL-13501 - Pacific Northwest National Laboratory
PNNL-13501 - Pacific Northwest National Laboratory
PNNL-13501 - Pacific Northwest National Laboratory
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Modeling the Sequestration of CO2 in Deep Geological Formations<br />
Study Control Number: PN00068/1475<br />
K. Prasad Saripalli, Ashok Chilakapati, Pete McGrail<br />
The Department of Energy has identified carbon management as a critical component of its mission. This project is<br />
developing the analytical and numerical tools needed by DOE to evaluate management alternatives involving carbon<br />
sequestration in deep geologic formations.<br />
Project Description<br />
The purpose of this project is to develop analytical and<br />
numerical models to evaluate carbon sequestration in<br />
deep geologic formations. Specifically, these tools are<br />
needed to evaluate issues such as the capacity of the<br />
geologic formation around a carbon injector, the relative<br />
apportioning of carbon mass among the three states<br />
(hydrodynamic, dissolved, and mineral phase), the longterm<br />
fate of sequestered CO2, the potential for CO2<br />
release, and the effect of formation plugging on CO2<br />
injection. Equations governing the radial injection of CO2<br />
into deep saline aquifers, axisymmetric flow of CO2<br />
around the injector, and eventual buoyancy-driven<br />
floating with simultaneous dissolution were formulated.<br />
Two models were prepared: the semi-analytical model<br />
PNLCARB and the numerical model STOMP-CO2. The<br />
models effectively simulate deep-well injection of waterimmiscible,<br />
gaseous, or supercritical CO2. The models<br />
were used to investigate the effect of pertinent fluid and<br />
reservoir and operational characteristics on the deep-well<br />
injection of CO2. The results indicated that the injected<br />
CO2 phase initially grows as a bubble radically outward,<br />
dissolves partially in the formation waters, eventually<br />
floats toward the top due to buoyancy, and settles near the<br />
top confining layer. Formation permeability, porosity, the<br />
rate and pressure of injection, and the rate of CO2<br />
dissolution influenced the growth and ultimate<br />
distribution of the CO2 phase. The first-generation tools<br />
developed by this project will help to evaluate and<br />
optimize methods for sequestering carbon in deep<br />
geologic repositories.<br />
Introduction<br />
Geological sequestration of CO2 has been recognized as<br />
an important strategy for reducing the CO2 concentration<br />
in the atmosphere. However, economically viable<br />
technologies for geological sequestration and models<br />
describing the same are in their infancy. This project<br />
focused on modeling the injection, sequestration, fate, and<br />
escape of CO2 in geological formations. The three<br />
mechanisms of CO2 sequestration are hydrodynamic,<br />
dissolved, and mineral phase trapping. These<br />
mechanisms can influence one another; for example, in<br />
addition to providing a carbon sink, mineral trapping can<br />
significantly alter hydrogeologic properties (such as<br />
secondary porosity and permeability) and hence, the<br />
efficiency and capacity for hydrodynamic and dissolved<br />
trapping. Dissolved-phase trapping, a strong function of<br />
pressure, salinity, and temperature, can similarly<br />
influence the other two processes. As such, modeling<br />
geological sequestration requires an accurate<br />
representation of the individual processes and their<br />
interaction. Following are the primary processes that<br />
need to be considered in modeling geological<br />
sequestration: 1) multiphase, radial injection of CO2 and<br />
the growth of its area of review around the injector, 2)<br />
buoyancy-driven migration of CO2 toward the top aquifer<br />
confining layer, 3) dissolution of CO2 during injection<br />
and vertical migration, and the resulting aqueous<br />
speciation of carbon, 4) carbon mass exchange via<br />
precipitation and dissolution of minerals through the<br />
interaction of dissolved and gaseous phase CO2 with the<br />
formation, and 5) changes in hydrogeological properties<br />
due to mineral trapping and the resulting formation<br />
damage and injectivity decline. The reservoir-scale<br />
numerical codes typically do not model the above<br />
processes around an injection well with adequate<br />
mechanistic detail. Over the past several years, our team<br />
developed significant expertise in many of these<br />
multiphase and reactive transport processes, and their<br />
modeling for deep-well waste injection applications. This<br />
experience can be combined to develop effective<br />
modeling tools for geological sequestration of CO2.<br />
Approach<br />
Two mathematical models were developed for the<br />
injection, sequestration, distribution, and long-term fate,<br />
including release to the atmosphere, of CO2. One of them<br />
is PNLCARB1.0, a semi-analytical model for modeling<br />
the injection and sequestration around a single injection<br />
well. Governing equations were derived for the radial<br />
Earth System Science 233