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Chapter 1 Synopsis and Executive Summary 1.5 Geothermal Drilling Technology and Costs 118 Well costs are a significant economic component of any geothermal development project. For lower grade EGS, the cost of the well field can account for 60% or more of the total capital investment. For making economic projections, estimates of well drilling and completion costs to depths of 10,000 m (30,000 ft) are needed for all grades of EGS resources. Drillsite specifics, stimulation approaches, well diameters and depths, and well production interval lengths and diameters are just some of the parameters that need to be considered. Drilling records for geothermal wells do not exist in sufficient quantity or detail for making such projections. In recent years, there have been fewer than 100 geothermal wells drilled per year in the United States and very few of them are deeper than 2,800 m (9,000 ft), which provides no direct measure of well costs for deeper EGS targets for the long term. Insight into geothermal well costs is gained by examining trends from experience in the oil and gas welldrilling industry. Thousands of oil and gas wells are drilled each year in the United States, and data on their costs are available on a yearly basis from the American Petroleum Institute’s Joint Association Survey (JAS) (see API, 2006). Additionally, the similarity between oil and gas wells and geothermal wells makes it possible to develop a drilling cost index that can be used to normalize any geothermal well cost from the past three decades to present current values, so that the well costs can be compared on a common dollar basis. Because of the limited data available for geothermal drilling, our analysis employed the Wellcost Lite model, developed by Bill Livesay and coworkers at Sandia National Laboratories during the past 20 years, to estimate the cost of EGS wells. The model can accommodate expected ranges in a multitude of parameters (well diameter, bit life, penetration rate, casing design, geologic formation conditions, etc.). Improvements in drilling technology can also be incorporated into the model, as well as directional drilling with multilateral completion legs. Wells in the depth ranges from 1,500 m (4,920 ft) to 10,000 m (32,800 ft) were modeled in three categories: shallow wells (1,5003,000 m), mid range wells (4,0005,000 m), and deep wells (6,00010,000 m). EGS well costs are significantly influenced by the number of casing strings used. For example, two 5,000 mdeep wells were modeled, one with four casing intervals and another with five casing intervals. Whereas the former requires fewer casing intervals, the increased lengths of individual sections may raise concerns about wellbore stability. This is less of a risk if more casing strings are used, but costs will be adversely affected by an increase in the diameter of the upper casing strings, the size of the rig required, and a number of other parameters. The 6,000 m well was modeled with both five and sixcasing intervals. Costs for the 7,500 m and 10,000 m wells were estimated using six casing intervals. Shallow wells at depths of 1,500, 2,500, and 3,000 m are representative of current hydrothermal practice. Predicted costs from the Wellcost Lite model were compared to actual EGS and hydrothermal well drillingcost records, where available. Figure 1.8 shows the actual costs of geothermal wells, including some EGS wells. The costs predicted by the Wellcost Lite model show adequate agreement with actual geothermal well costs, within the normal ranges of expected variation for all depths.PDF Image | Synopsis and Executive Summary
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