But does the fact that they've made an assumption on which to base modeling actually a statement on what might be the rate of change or is it a convenient, non-controversial metric to use for demonstrating what could potentially happen as the changeover unfolds?
Presuming for the moment the below study is an accurate assessment, what do you see as the implications other than "we're screwed"?
http://www.democraticunderground.com/discuss/duboard.php?az=view_all&address=115x243896Journal of Petroleum Science and Engineering
Volume 70, Issues 1-2, January 2010, Pages 123-130
doi:10.1016/j.petrol.2009.11.002
Copyright © 2009 Elsevier B.V. All rights reserved.
Sequestering carbon dioxide in a closed underground volume
Christine Ehlig-Economidesa, 1, E-mail The Corresponding Author and Michael J. Economidesb, Corresponding Author Contact Information, E-mail The Corresponding Author
a Department of Petroleum Engineering, Texas A&M University, College Station, Texas 77843, USA
b Department of Chemical Engineering, University of Houston, Houston, Texas 77204, USA
Available online 20 November 2009.
Abstract
The capture and subsequent geologic sequestration of CO2 has been central to plans for managing CO2 produced by the combustion of fossil fuels. The magnitude of the task is overwhelming in both physical needs and cost, and it entails several components including capture, gathering and injection. The rate of injection per well and the cumulative volume of injection in a particular geologic formation are critical elements of the process.
Published reports on the potential for sequestration fail to address the necessity of storing CO2 in a closed system. Our calculations suggest that the volume of liquid or supercritical CO2 to be disposed cannot exceed more than about 1% of pore space. This will require from 5 to 20 times more underground reservoir volume than has been envisioned by many, and it renders geologic sequestration of CO2 a profoundly non-feasible option for the management of CO2 emissions.
Material balance modeling shows that CO2 injection in the liquid stage (larger mass) obeys an analog of the single phase, liquid material balance, long-established in the petroleum industry for forecasting undersaturated oil recovery. The total volume that can be stored is a function of the initial reservoir pressure, the fracturing pressure of the formation or an adjoining layer, and CO2 and water compressibility and mobility values.
Further, published injection rates, based on displacement mechanisms assuming open aquifer conditions are totally erroneous because they fail to reconcile the fundamental difference between steady state, where the injection rate is constant, and pseudo-steady state where the injection rate will undergo exponential decline if the injection pressure exceeds an allowable value. A limited aquifer indicates a far larger number of required injection wells for a given mass of CO2 to be sequestered and/or a far larger reservoir volume than the former.