This project successfully implemented an approach to jointly image time-lapse changes in water and steam concentrations and subsurface flow in a geothermal reservoir, using data from small earthquakes and magnetotelluric observations. The project advanced the technology by imaging time-lapse changes of the two data sets, based on different physical properties, for the first time. The project demonstrated this technology at The Geysers geothermal field in Northern California over an area of approximately 75 square kilometers, where seismic and magnetotelluric data were collected over several years. The project team collected seismic data from over 280,000 earthquakes and collected three magnetotelluric surveys to generate images of water and steam volumes as well as flow paths and barriers in the geothermal reservoir. Correlation of the geophysical images with known water injection and steam production volumes allowed the team to calibrate the data and to gain confidence in the results, which can now be applied throughout the reservoir, where borehole data are unavailable. The results of the joint imaging, together with reservoir data derived from observations in boreholes, allow interpretation of the images to identify water and steam saturated zones, as well as fluid pathways and barriers. This information allows the reservoir operator to improve its drilling program by minimizing drilling of unsuccessful wells, resulting in reduced costs and lower electricity rates for California ratepayers.

In the last 10 years, coalbed methane (CBM) has transformed from a coal-mine hazard to a clean burning source of long term natural gas. The benefit of methane as an energy source in conjunction with vast amounts stored in coal basins has led to the development of an industry that produces CBM. Reducing the emission of green house gases to the atmosphere through carbon dioxide injection into coal has added a dual benefit to the production of CBM, as carbon dioxide may be used to desorb methane from coal seams, sequestering the CO2. CBM is present in coal seams as a product of the coalification process. Methane gas is typically extracted by depressurizing the reservoir by removing water. This allows the gas to desorb from the coal matrix and flow through the cleat structure to a production well. In order to increase CBM production, more information is needed on the migration of methanethrough fractures and cleats. A better understanding of the replacement of methane by carbon dioxide in the coal seam is also needed to further understand this sequestration method. Laboratory experiments are underway to address these questions. Tests on core samples are currently performed under in-situ pressure to gain insight on processes occurring in CBM extraction and carbon dioxide sequestration. We use electrical resistivity and x-ray computed tomography (CT) scanning to determine saturation and spatial phase distribution. Flowrate, in conjunction with upstream and downstream pressure measurements, is used to determine sample permeabilty. Additionally, simultaneous measurements of seismic waves are performed to obtain P- and S-wave velocities as well as amplitudes of body waves as a function of methane and carbon dioxide state and saturation in the coal. Initial results will be presented showing the permeability structure of a coal sample, and seismic waveforms obtained during methane production by depressurization and during gaseous and liquid CO2 injection. Mass transfer limitations that may ultimately affect processes and parameter changes, were not observed in the short-duration tests. Technique refinement and additional testing using a variety of coal samples are still needed to provide a larger database of coal behaviors under conditions of interest. The results of laboratory studies on CBM can be used to design field experiments to monitor temporal changes during CBM production.