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geothermal is similar to slightly less in cost. Lu- kawski (2013) concluded that the geothermal com- munity should not use the oil and gas cost indices to normalize the cost of geothermal wells. Once the reservoir is drilled, testing is needed; Randy Normann (2013) of Perma Works discussed how the Hydro-Fracturing Monitoring Tool is able to ‘‘run barefoot’’ (no heat shield) up to 570°F (299°C) under high pressure and stay in the reservoir for weeks to years without removing the logging tool. This allows for long-term monitoring of chan- ges in the well and reservoir such as testing changes in injection or production, well connectivity, shut-in testing, reservoir pull down test, and power plant maintenance. This capability will change our understanding of the life of a reservoir system, pressure fluxes, and how to improve stimulation. Tools capable of these harsh conditions make high- temperature EGS projects more viable. A key factor driving the rapid improvement in equipment is the ability of manufacturers to meet the needs of both the geothermal and waste heat to power communities with the same technology. Highlighting the small-scale (<100 kW) environments, Fox (2013) of ElectraTherm discussed improvements in their Green Machine after a demo at an oil well in Missis- sippi and how the same technology is being deployed rapidly into the European market to meet the demand for waste heat applications. With fluid temperatures in the 190–240°F (88–116°C) temperature range, a number of oil and gas operations become viable for waste heat energy capture including coproduced hot fluids, compressor stations, natural gas well head flaring, and amine sweetening plants. Ronzello (2013) of Pratt and Whitney Power Systems discussed the expected outcome from the acquisition by Mitsubishi Heavy Industries of the PWPS/Turboden ORC equipment line, which ran- ges from small to medium sized (1–10 MW). Ronz- elloÕs graphic on efficiency as a function of resource and surface temperature clearly explained the ben- efit of utilizing the highest heat sources. In his example, similar equipment efficiency can range between 7.5% and 25%, depending upon the source temperature variations, i.e., 195°F and 590°F (91 and 310°C), respectively. This emphasized the impor- tance of the temperature rather than industry or source of the temperature: such as biomass, geo- thermal, waste heat, CHP, etc. Trying to contain excitement, Dickey (2013) of TAS Energy (Turbine Air Systems) showed pictures of their first project on ‘‘un-separated mixed hydro- carbons’’ in California at a mid-stream oil production facility. This project had fluid temperature of 300°F (149°C) from the ground at 38,000 lbs (17,236 kg)/h and is from a steam flood. The expander was designed for a 1.2 MW output with actual gross output of 750 kW and a net of 500 kW. It was expected that this site has a potential of 1 MW gross output. The second part of HalleyÕs talk was on a ‘‘geopressured inte- grated hybrid system’’ that TAS is working on in the Gulf Coast region. Geopressured hybrid systems were proven at Pleasant Bayou in Brazoria County, Texas in the late 1980s with a nominal 1.0 + MW output from heat in the produced water and natural gas burned on site. This project would expand the previ- ous work by incorporating a binary system with the un-separated mixed hydrocarbon approach along with waste heat recovery from engine exhaust and jacket water, and other efficiency improvements, for an integrated hybrid system producing 3.5 MW from some 25,000 BBLs (3,975 m3) per day of produced fluid. Filters would be used for particulate capture should this be necessary. For the first time, two newly developed pressure- related power systems were publicly viewable on the SMU Campus for the Geothermal Conference. Ker- lin (2013) displayed their Helidyne planetary ex- pander, named after the similarities to the sun/planets relationship for the machineÕs extremely high-preci- sion rotating system with no belts or gears. This state- of-the-art expander is designed to work with natural gas applications such as J–T valves, wellhead chokes, gas processing plants, let-down stations, and, where possible, geothermal geopressured wells. The second system, the Langson Helical Screw Energy Converter, developed by Richard Langson (DiPippo and Langson 2013), was installed in the SMU Campus boiler room to run the pressure equipment and is capable of installation/removal in just hours. The machine greened-up campus elec- tricity for a few hours during the day of its installa- tion. Being capable of using either water or steam, it allows for fluctuating flow rates or pressure changes, making it applicable in numerous industry applica- tions, such as geothermal geopressure, petrochemi- cal, power plants, biogas, and on equipment in the oil and gas field. The system is scalable with sizing variations between 1 and 50 MW. Langson indicated that installation costs could be £ $1,500/kW with return on investment in 1.85 years. Instead of line shaft and submersible pumps for a high water cut well, the Gravity Head Pump is designed for installation without shafts, rods, or American Association of Petroleum Geologists, Energy Minerals DivisionPDF Image | Unconventional Energy Resources
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