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68 reversecirculation drilling (and tremmie tube cementing), is being tested as a solution to severe lost circulation in the tophole interval of some wells. The dualtube process provides a path for fluids to flow down the outer annulus and air to be injected in the annulus between inner tube and the outer tube. The combined effect is to airlift the cuttings and fluids inside the inner tube. The use of tremmie tubes to place cement at the shoe of a shallow (or not so shallow) casing shoe is borrowed from water well and mining drilling technology. This technique is helpful in cementing tophole zones, where severe lost circulation has occurred. Chapter 6 Drilling Technology and Costs 6.3 Historical WellCost Data In order to make comparisons between geothermal well costs and oil and gas well costs, a drilling cost index is needed to update the costs of drilling hydrothermal and EGS or HDR wells from their original completion dates to current values. There are insufficient geothermal wellcost data to create an index based on geothermal wells alone. The oil and gas well drilling industry, however, is a large and well established industry with thousands of wells drilled each year. Because the drilling process is essentially the same for oil, gas, and geothermal wells, the Joint Association Survey (JAS) database provides a good basis for comparison and extrapolation. Therefore, data from the JAS (API, 1976 Another solution to cementing problems in the presence of lost circulation is to drill beyond, or bypass, the loss zone and to cement using a technique that can prevent excessive loss. Lightweight cement, foamed cement, reverse circulation cement, and lightweight/foamed cement are developments that enable this approach to be taken. However, only lightweight cement has found widespread use. Selection of an appropriate cement is critical, because a failed cement job is extremely difficult to fix. Directional drilling. Directionally drilled wells reach out in different directions and permit production from multiple zones that cover a greater portion of the resource and intersect more fractures through a single casing. An EGS power plant typically requires more than one production well. In terms of the plant design, and to reduce the overall plant “footprint,” it is preferable to have the wellheads close to each other. Directional drilling permits this while allowing production well bottomspacings of 3,000 ft. (900 m) or more. Selective bottomhole location of production and injection wells will be critical to EGS development as highlighted in Chapters 4 and 5. The tools and technology of directional drilling were developed by the oil and gas industry and adapted for geothermal use. Since the 1960s, the ability to directionally drill to a target has improved immensely but still contains some inherent limitations and risks for geothermal applications. In the 1970s, directional equipment was not wellsuited to the hightemperature downhole environment. High temperatures, especially during air drilling, caused problems with directional steering tools and mud motors, both of which were new to oil and gas directional drilling. However, multilateral completions using directional drilling are now common practice for both oil and gas and geothermal applications. The development of a positive displacement downhole motor, combined with a realtime steering tool, allowed targets to be reached with more confidence and less risk and cost than ever before. Technology for reentering the individual laterals for stimulation, repair, and workovers is now in place. Directional tools, steering tools, and measurementwhiledrilling tools have been improved for use at higher temperatures and are in everyday use in geothermal drilling; however, there are still some limitations on temperatures.PDF Image | Drilling Technology and Costs
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