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agency or group operating on different time sched- ules. Reservoir Management. Every geologist knows that geothermal energy is a vast resource, based solely on the makeup of our planet. The difficulty is in retrieving it for use and support of our technical infrastructure. Much of the geothermal production has historically occurred in the western states, with EGS technology opening areas where low-temper- ature geothermal reservoirs can be used for various purposes. Bedre and Anderson (2012) from West Virginia University presented a paper discussing sensitivity analysis of low-T reservoirs and the direct use of geothermal energy. While they indicated that the eastern U.S. has lower temperature gradients than many of the western states, West Virginia has a higher gradient compared to other eastern states. Of course, knowledge of this fact has been the direct result of much greater drilling in places such as the Appalachian Basin for oil and reservoirs. For example, these data have resulted in identifying a hot spot in the eastern part of West Virginia where temperatures reach 300°F (149°C) at a depth of around 14,700–16,400 ft (4,481–4,999 m). Bedre and Anderson (2012) performed a sensitivity analysis of a reservoir at this temperature at a depth of 16,400 ft (4,999 m), using seven natural and human controlled parameters within a geothermal reservoir: reservoir temperature, injection fluid temperature, injection flow rate, porosity, rock thermal conductivity, water loss (%), and well spacing. A 30-year timeframe of operation was used to run the reservoir simulation. Their results indicated that reservoir temperature was the most important parameter affecting pro- duction. Variations in porosity and rock thermal conductivity did not affect the reservoir perfor- mance significantly. Other factors had varying levels of impact, with reservoir temperature or injection flow rate having the greatest impact. Resource Assessment. There has been a renewed interest in recovering the geothermal energy stored in sedimentary basins for electricity production. With exploration for oil and gas resources and well logs, temperatures at depth, and reservoir properties such as depth to basement and formation thickness are better known than in many conventional geo- thermal areas. The availability of these data reduces exploration risk and allows development of explo- ration models for each basin. Porro et al. (2012) of NREL presented estimates in the magnitude of recoverable geothermal energy from 15 major U.S. sedimentary basins and ranked these basins relative to their potential. Total available thermal resource per basin was estimated using the volumetric heat- in-place method, and a qualitative recovery factor was determined for each basin based on data on flow volume, hydrothermal recharge, and vertical and horizontal permeability. A more in-depth study is necessary to better determine recovery factors for each basin. [Of interest is that onshore Gulf of Mexico was not included in this study, where past efforts produced viable geothermal energy.] Turning from the regional U.S. basin study to a specific basin, Bohlen (2012) presented a pre- liminary geothermal resource assessment for the Raton Basin in Colorado. While Colorado has sub- stantial thermal resources, slow geothermal progress has generally been due to geological complexities, rugged terrains, and ‘‘not in my back yard’’ attitudes that have prevented serious development. A number of rock samples have been taken from the outcrop of Raton Basin rocks to determine thermal conductiv- ity in the laboratory. Surface and BHT data were available from 1,172 active gas wells in the Raton Basin from an operating producer. Total depths ranged from just over 650 to over 7,200 ft (198– 2,195 m). The majority (999 wells) are less than 3,200 ft (975 m) and go no deeper than the Pierre Shale. Using the well data and conductivity values, thermal gradients and heat flow were calculated for 3,200; 6,500; and 9,800 ft (975; 1,981; and 2,987 m) depths, indicating higher temperatures at depth than previously thought. All of the analyses resulted in a picture of the Raton Basin being a far better can- didate for geothermal power production than pre- viously thought. SMU Geothermal Conference—March 13–14, 2013 No geothermal conference was held at SMU in 2012 as there was conflict with other geothermal meetings around the country and the fact that the SMU personnel were busy in participation in these conferences, such as at the AAPG Annual meeting. However, an SMU Geothermal Laboratory Con- ference on Geothermal Energy and Waste Heat to Power: Utilizing Oil and Gas Plays was held in March, 2013 with 171 attendees, 24 oral presenta- tions, and 10 poster presentations. The AAPG- EMD geothermal committee was represented by David Blackwell and Paul Morgan. Notes recorded American Association of Petroleum Geologists, Energy Minerals DivisionPDF Image | Unconventional Energy Resources
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