Saline Formation Simulation Sample Clauses

Saline Formation Simulation. Xxxxxxxxxxxx Xxxxxxxxx, University of Alabama at Birmingham Simulation of CO2 injection and analysis of the fate of CO2 injected into saline formations were not explicitly called for in the original statement of work, though the possibility of CO2 storage in formations adjacent to the oil reservoir is mentioned in the text of the proposal and contract. It has become increasingly clear that the saline formations above, between, and below the oil-bearing strata are likely to have much larger capacity for storage of CO2 than the depleted oil reservoirs, so this topic has assumed greater importance. 2.10. Visualization of Geologic Structure and Flows Xxxx Xxxx, University of Alabama at Birmingham ` Xxxx Xxxxxx, Geological Survey of Alabama Xxxx Xxxxxxx, University of Alabama Xxxxxxxxxxxx Xxxxxxxxx, University of Alabama at Birmingham Task 13. Visualization of geologic structure and flows. Display, in the UAB Enabling Technology Laboratory and on the project web site, of the geologic structure in the vicinity of the test xxxxx and the results of the calculations of oil, water, and CO2 flows using the reservoir simulator.

Saline Formation Simulation. Xxxxxxxxxxxx Xxxxxxxxx and Xxxxx Xxxxx, University of Alabama at Birmingham Simulation work during the quarter under review has been focused entirely on the oil reservoir, to confirm the suitability of the amount of CO2 planned for injection during the first test and to estimate the time required to inject the CO2 and observe enhanced oil recovery. We will return to simulation of saline formations during the next quarter.

Saline Formation Simulation. The total storage capacity of Citronelle Dome, including saline formations in the Lower and Upper Tuscaloosa Groups and Eutaw Formation, and the Xxxxxxx Xxxxx of the Rodessa Formation is estimated to be in the range from 500 million to 2 billion short tons of CO2. The TOUGH2 numerical simulation program for multi-phase fluid flow in porous and fractured media, from Xxxxxxxx Berkeley National Laboratory (Pruess, Oldenburg, and Moridis, 1999) and the accompanying fluid property module, ECO2N (Xxxxxx, 2005), specifically designed for study of CO2 storage in saline formations, are being implemented to refine these calculations, determine injectivity of the formations, and assess the long-term migration and fate of stored CO2, including mineralization. Preliminary estimates of the potential for leakage of CO2 through cap rock, based upon the analysis by Xxxx (1975), indicate that leakage is not expected from any of the formations considered above as storage reservoirs. However, a refined assessment using more accurate values for the input parameters (brine-CO2 surface tension and pore radii in reservoir rock and seals) is recommended.